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The Estate of tne Late 
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ABITIBI CANYON POWER DEVELOPMENT 

Dam and power house from Canyon walls of taiirace. 

The aggregate height of the structure from top of dam to normal tailwater level is about 250 feet. 

Note the figures on the top of the power house roof. 



/twenty-sixth Vnnual report 



OF THE 

HYDRO-ELECTRIC POWER 
COMMISSION 

OF THE 

PROVINCE OF ONTARIO 

FOR THE YEAR ENDED OCTOBER 31st 

1933 



PRINTED BY ORDER OF 
THE LEGISLATIVE ASSEMBLY OF ONTARIO 




ONTARIO 



TORONTO 
Printed and Published by Herbert H. Ball, Printer to the King's Most Excellent Majesty 

1934 



THE 

HYDRO-ELECTRIC POWER COMMISSION 
OF ONTARIO 



Hon. J. R. Cooke, M.L.A Chairman 

C. Alfred Maguire Commissioner 

Rt. Hon. Arthur Meighen, P.C., K.C. . . Commissioner 

W. W. Pope Secretary 

F. A. Gaby, B.A.Sc, D.Sc Chief Engineer 



LIBRARY 

727496 

UNIVERSITY OF TORONTO 



To His Honour 

The Honourable Herbert A. Bruce, R.A.M.C, M.D., F.R.C.S., 

Lieutenant-Governor of Ontario 

May It Please Your Honour: 

The undersigned has the honour to present to your Honour the Twenty-sixth 
Annual Report of The Hydro-Electric Power Commission of Ontario for the fiscal 
year ending October 31, 1933. 

This Report covers all of the Commission's activities and also embodies 
the financial statements, for the calendar year 1933, of the municipal electric 
utilities operating in conjunction with the various systems of the Commission 
and supplying electrical service to the citizens of the Province. 

Dealing, as it does, with a multiplicity of activities relating to several 
electrical systems obtaining power from thirty-nine hydro-electrical developments 
operated by the Commission, supplemented by power purchased from other 
sources, and recording financial and other data relating to the individual local 
municipal electric utilities, the Annual Report presents a large amount of 
statistical information, much of which must, of necessity, be of a summary 
character. 

The financial statements, the statistical data and the general information 
given, however, are so arranged and presented as to give a comprehensive 
survey of the Commission's operations. Not only does the Report record the 
progress made during the past year, but it gives, in addition, certain cumulative 
results for the various periods during which operation has been maintained 
in the respective municipalities. 

At the end of the fiscal year the number of municipalities served in Ontario 
by the Commission was 757. This number included 27 cities, 96 towns, 269 
villages and police villages and 365 townships. With the exception of 13 
suburban sections of townships known as voted areas, the townships and 91 
of the smaller villages are served as parts of 171 rural power districts. 

Constructional Activities 

During 1933 the chief item of constructional work was the completion 
to its initial operating stage of the Abitibi Canyon development on Abitibi 

[vj 



vi TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

river. This work was carried out by the Commission for the Provincial 
Government. A description of the development will be found in Section IV 
of this Report. 

Electrical construction work was confined chiefly to transformer stations 
for the supply of electric power to a number of Paper Companies to enable them 
to utilize secondary power in the generation of process steam. The Ontario 
Paper (Steam) transformer station, Thorold, with a capacity of 67,500 kv-a. 
in transformers and 90,000-kw. in electric steam generators, was installed and 
placed in service on February 2, 1933. At the Great Lakes Paper (Steam) 
transformer station Fort William two 8,000-kw. electric steam generators were 
installed and placed in service on October 1, 1933. At Provincial Paper (Steam) 
transformer station Port Arthur two 12,000-kv-a. transformers and two similar 
capacity electric steam generators are being installed. Further installations of 
a similar nature are under consideration. 

Taking advantage of the relatively smaller amount of construction work 
many improvements are being made to the stations and equipment on the various 
systems. 

Operating Conditions 

The past year's operation of the systems has been satisfactory. Few inter- 
ruptions to service occurred and failures of equipment were relatively few and 
not serious in extent. 

Rainfall was much below normal and seriously reduced the stream flow and 
the capacity of the generating plants on the Eastern Ontario and Georgian Bay 
systems. On the Georgian Bay system the reduction in generating capacity was 
offset by an increased transfer of power from the Niagara system. On the 
Eastern Ontario system the low stream flow during certain periods reduced the 
capacity of all the generating stations on the Trent river to less than 40 per cent 
of their normal maximum capacity. A severe power shortage would have been 
experienced if a supplementary supply of reserve power had not been available 
from the Gatineau Power Co. The Nipissing district also experienced a period 
of low precipitation, but the storage works constructed by the Commission made 
it possible for the stream flow to be maintained in volume adequate to supply 
the demand for power. 

The Commission has continued its efforts to protect the life and beauty of 
trees along the public highways on which power lines are situated. The Commis- 
sion's Forestry Division employs men especially trained for this work, which has 
been carried out so as to protect the power lines and give reliable service without 
seriously impairing the beauty of the trees. The Commission's efforts in this 
respect have invoked many expressions of appreciation from highway and 
municipal authorities. 

Cost of Electrical Service Furnished by the Commission 

The function of the Commission is not only to use its best endeavours to 
provide for the people of Ontario an adequate and reliable supply of electrical 
energy, but also to ensure that the cost of that electrical energy to the consumers 
shall be the minimum consistent with the financial stability of the enterprise. 



1934 HYDRO-ELECTRIC POWER COMMISSION vii 

The success that has been attained in the accomplishment of the latter object 
may be appreciated by a careful study of the actual rates to consumers as 
presented in Statement "E," and of the statistical data setting forth the results 
that have been attained for the consumers under these rates, as presented in 
Statement "D," in conjunction with the various financial statements of the 
Report. 

The bill for retail service rendered, is the practical aspect of Hydro service 
with which the average consumer is most concerned. It is, therefore, a 
satisfaction to note that except in a very few cases the rates for service during 
the period of depression have been maintained at their low levels or have been 
made lower. 

The knowledge that there are substantial reserves of power is a distinct 
encouragement to the industrial organizations of the Province. Moreover, not- 
withstanding the generous use made of electrical service by the domestic and 
rural consumers in Ontario, there is still a large potential market for numbers 
of electrical appliances which the low cost of electricity makes it economically 
practicable to use. 

Low Rates for Domestic Hot-Water Heating 

The slackening in demand for power for industrial purposes has enabled 
the Commission to encourage further use of power for domestic service. The 
hot-water heater campaign inaugurated during the year 1933 has been successful 
and incidentally has resulted in the development of better electric water-heating 
equipment than was previously available. The heaters are installed without 
capital cost to the consumer, but even at the low rates approved for their operation 
the revenue obtained is usually sufficient to defray their initial cost in less than 
a year. Thereafter their continued use results in increased revenue to the 
municipal utilities and to the system. From the consumers' standpoint the 
benefits of this service are greatly appreciated. 

Load Conditions 

The demand for power from the Commission's systems has increased during 
the year, as shown by the table given below : — 

October December October December 

1932 1932 1933 1933 
Niagara system, 25 cycle (Canadian loads 

only) 816,505* 786,059 961,059 1,060,268 

Other systems, total 239,438 251,898 311,038 379,778 



Grand total (Canadian loads only) 1,055,943* 1,037,957 1,272,097 1,440,046 



Note. — Power resold to the Gatineau Power Co. is included in the above table. The 1932 figures 
which are affected are indicated by an asterisk. 

Both this table and the table which follows are similar to the tables which 
appeared in last year's Annual Report. In order to make the 1932 figures strictly 
comparable with those of 1933 it has been necessary to include in October, 1932, 
27,500 horsepower which was resold to the Gatineau Power Company in that 
month. Further particulars regarding this change are given in the operating 
section of the Report. 



viii TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

The total Canadian loads during the months of October and December, 
1933, were very much greater than the loads for the corresponding months of 
1932. The greater part of the increase is in secondary power, the sale of which is 
of advantage both to the Commission and to industry, so long as it can be 
supplied. There is, however, an important though less pronounced increase in 
the primary or firm load which occurred during the latter part of the year and 
which has been persistently maintained over a considerable period in a way 
which is most encouraging. 

In last year's Report reference as made to the fact that the marked down- 
ward trend of load in 1931 had been largely arrested, and that the decrease in 
1932 was very slight. During December of 1932 and January of 1933, further 
decreases occurred, but since April, 1933, the trend has been steadily upward. 
By the end of the fiscal year, October 31, 1933, all ground lost during the first 
part of the year had been regained, and the year closed with a net increase. This 
gain for 1933 seems of special significance when compared with the losses of 1931 
and 1932. The load losses of 1931 and 1932 have not yet been completely 
regained, and the rate of increase for the firm load in 1933 is not as great as the 
average rate of increase established over a long period of years prior to the 
depression. Therefore, the effects of the industrial depression are still apparent 
in the statistics for load during 1933, but after the sharper effects of the depression 
in 1931 and 1932, it is encouraging to find that 1933 shows actual improvement. 

The following tabulation corresponds to that given for several years in this 
place in the Report, and shows the power supplied to the various systems at the 
close of the fiscal and calendar years. The figures given show the total load of 
each system and therefore include power exported as well as secondary power 
and primary power. The figures given for the Niagara system do not correspond 
to those shown in the table given above, as the first table covers Canadian load 
only, exclusive of export, whereas the second table shows the total load including 
export. 

DISTRIBUTION OF POWER TO SYSTEMS 

20-Minute Peak Horsepower 
System Coincident Peak 

October December October December 

System 1932 1932 1933 1933 

Niagara system 25 cycle. 867,446* 838,338 1,055,697 1,134,262 

Dominion Power and Transmission system 43,968 48,525 45,710 51,743 

Georgian Bay system 25,666 26,424 23,887 25,496 

Eastern Ontario system 80,544 86,716 86,890 116,127 

Thunder Bay system 65,700 63,800 90,450 120,000 

Manitoulin rural power district 80 84 

Northern Ontario Properties: 

Sudbury district \ 177A1 in r 7 , / 12,466 12,802 

Abitibi district / 17 ' 701 2U ' 5/0 \ 45,389 46,890 

Nipissing district 3,751 3,799 3,539 3,901 

Patricia district 2,048 2,058 2,627 2,735 

Totals 1,106,884* 1,090,236 1,366,735 1,514,040 

*\<>TE. — Power resold to the Gatineau Power Co. is included in the above table. The 1932 figures 
which are affected are indicated by an asterisk. 



1934 HYDRO-ELECTRIC POWER COMMISSION ix 

Financial Summaries 

The financial statements embodied in this Report are presented in two main 
divisions, namely, a division — Section IX — which deals chiefly with the operations 
of the Commission in the generation, transformation and transmission of electrical 
energy to the co-operating municipalities; and a division — Section X — which 
deals with the various operations of the municipal electric utilities in the localized 
distribution of electrical energy to consumers. In Section IX, "Rural Operating" 
reports are also given, which summarize the results of the local distribution of 
rural electrical service by the Commission to the individual consumers in rural 
power districts. This work is performed by the Commission on behalf of the 
respective townships co-operating to provide rural service. 

The cumulative results of the operation of the several systems of the 
Commission as set forth in this Report demonstrate a sound financial condition. 



Capital Investment 

The total investment of the Hydro-Electric Power Commission of Ontario 
in power undertakings and hydro-electric railways is $285,003,969.26, exclusive 
of government grants in respect of construction of rural power districts' lines; 
and the investment of the municipalities in distributing systems and other assets 
is $109,657,573.64, making in power and hydro-electric railway undertakings a 
total investment of $394,661,542.90. 

The following statement shows the capital invested in the respective systems, 
districts and municipal undertakings : 

Niagara system $201,975,671 .41 

Chats Falls development 6,167,756.08 

Georgian Bay system 8,394,645 . 25 

Eastern Ontario system 19,372,833 . 44 

Thunder Bay system 18,630,772 . 18 

Manitoulin rural power district 32,625 .79 

Northern Ontario properties 23,790,137.37 

Hydro-Electric railways 2,076,924 . 94 

Office and service buildings, construction plant, inventories, etc 4,562,602.80 

$285,003,969.26 

Municipalities distributing systems and other assets (exclusive of $26,045,679.00 

of municipal sinking fund equity in H.E.P.C. system) — all systems 109,657,573 .64 

$394,661,542.90 



Revenue of Commission 

The revenue of the Commission derivable from the municipal utilities 
operating under cost contracts and from other customers with whom — on behalf 
of the municipalities — the Commission has special contracts, all within the 



x TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Niagara, Georgian Bay, Eastern Ontario and Thunder Bay systems, Manitoulin 
rural power district and Northern Ontario properties, aggregates $27,520,853.79. 

The following statement shows how this revenue has been appropriated: 

Revenue from municipal electric utilities and other power customers $27,520,853.79 

Operation, maintenance, administration, interest and other 

current expenses $27,275,570 . 17 

Reserves for sinking fund, renewals, contingencies and obsoles- 
cence provided in the year. 4,839,838 . 70 



$32,115,408.87 
Less: Appropriated from obsolescence and contingencies reserves 4,236,606.73 



27,878,802.14 



Net balance charged to municipalities under cost contracts $357,948.35 



In connection with the foregoing statement it should be noted that, in 
making its annual determinations of costs chargeable for power supplied to the 
participating municipalities, the Commission for many years has followed a 
policy which recognizes the desirability of stabilizing the costs per horsepower 
one year with another. Commencing with 1926 and continuing to 1930, there 
were included in the amounts set aside to the reserve for obsolescence and 
contingencies, additional sums designed to care for possible lean years that might 
come in the future. A proportion of these extra reserves was derived from the 
profitable employment of system reserve generating equipment. In 1933 the 
contingency reserve was drawn upon in the case of the Niagara system to the 
extent of $4,236,606.73. This relief was given to the municipalities in their cost 
of power to compensate for the increased costs and reduced revenues in the year. 
In all other respects the various reserves have continued to be accumulated on 
the same basis as formerly, with the result that in the aggregate the reserves 
of the Commission show a net increase for 1933 of $3,290,453.57 as compared 
with the totals at the end of 1932. 



Rural Electrical Service 

During the past few years very substantial progress has been made in 
Ontario in the field of rural electrification. Practically all rural electrical 
service is now given through rural power districts which are operated directly 
by the Commission. There is now rather more than $17,690,000 invested in 
the rural power district systems established by the Commission. Towards 
this rural work the Ontario Government, pursuant to its policy of promoting 
the basic industry of agriculture, has, in the form of grants-in-aid, contributed 
50 per cent of the costs of transmission lines and equipment, or some $8,750,000. 
A total of 9,244 miles of transmission lines have been constructed to date, of 
which 326 miles were constructed during the past year. There are now about 
62,000 customers supplied in the rural power districts. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



XI 



RURAL 


POWER E 


USTRICT 


S— OPER/ 


lTIONS FOR THE 


YEAR 1933 




Niagara 
system 


Georgian 

Bay 

system 


Eastern 
Ontario 
system 


Thunder 

Bay 
system 


Mani- 

toulin 

rur. power 

district 


Nor. Ont. 

Nipissing 

district 


Totals 


Cost of power as 
provided to be 
pai d under 
Power Commis- 
sion Act 

Cost of operation, 
maintenance 
and administra- 
tion 


$ c. 
810,110.29 

557,105.44 
294,442.54 
251,397.57 

125,698.79 
66,871.35 


$ c. 
107,127.66 

56,844.72 
36,600.19 
28,890.44 

28,890.44 
7,986.56 


$ c. 
193,481.31 

121,212.84 
77,164.46 
62,925.98 

31,462.99 
16,863.37 


$ c. 
3,591.41 

3,509.95 
2,307.24 
1,738.59 

869.29 

457.68 


$ c. 
3,281.25 

1,447.26 

1,434.09 

996.29 

476.90 
285.45 


$ c. 
4,115.38 

2,818.63 
926.80 
723.40 

361.70 
194.22 


$ c. 
1,121,707.30 

742,938.84 


Interest 


412,875.32 


Renewals 

Obsolescence and 

contingencies . . 

Sinking fund .... 


346,672.27 

187,760.11 
92,658.63 


Total expenses. . . 

Revenue from 

customers 


2,105,625.98 
2,063,370.73 


266,340.01 
236,399.48 


503,110.95 
470,228.73 


12,474.16 
9,275.86 


7,921.24 
6,537.40 


9,140.13 
10,211.29 


2,904,612.47 
2,796,023.49 


Net surplus, all 
districts 












1,071.16 


1,071.16 


Net deficit, all 
districts 


42,255.25 


29,940.53 


32,882.22 


3,198.30 


1,383.84 


109,660.14 


Net deficit, all 
systems 














108,588.98 



















As indicative of the steady progress being made by co-operative effort 
between the Commission and the rural consumers in reducing the cost of electrical 
service, it may be stated that whereas in 1929, 7,700 consumers were being served 
in 13 rural power districts in which the primary rate was 3 cents per kilowatt- 
hour; in 1933 more than 21,000 consumers in 23 rural power districts were enjoying 
a primary rate of 3 cents or less per kilowatt-hour. During the same period the 
number of consumers in rural power districts where the highest primary rate of 
8 cents per kilowatt-hour was in force had diminished, notwithstanding the 
number of new districts in operation. Most of the consumers in the districts 
where the primary rate was 3 cents or less per kilowatt-hour had a follow-up rate 
of 1.5 cents or less per kilowatt-hour, while even the consumers in the districts 
where the primary rates were highest obtained additional energy over the 
reasonable class demand minimum at a rate of 2.0 cents per kilowatt-hour. All 
these rates are, of course, subject to the prompt payment discount of 10 per cent. 



Municipal Electric Utilities 

The following is a summation of the year's operation of the local electric 

utilities conducted by municipalities receiving power under cost contracts with 

the Commission: 

Total revenue collected bv the municipal electric utilities $30,627,841 .88 

Cost of power. $19,330,861 .58 

Operation, maintenance and administration 5,189,385.78 

Interest 2,426,286.35 

Sinking fund and principal payment on debentures 2,319,319.09 

29,265,852.80 



Amount available and set aside for depreciation and other reserve purposes $1,361,989.08 



xii TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

The setting-up of the reserves on rates customarily adopted in the past 
would have required an amount of $1,989,000.41, which is $627,011.33 in excess of 
the amount shown in the foregoing table as available for the present year. 
In this connection it is important to note that the municipal Hydro utilities 
provide for the retirement of their capital liabilities by either the instalment 
or sinking-fund method, and such payments are treated as part of the cost of 
the service. 

Reserves of Commission and Municipal Electric Utilities 

The total reserves of the Commission and the municipal electric utilities 
for sinking fund, renewals, contingencies and insurance purposes amount to 
$129,172,759.94 made up as follows: 

Niagara system $52,380,601 . 09 

Georgian Bay system 2,822,302 . 39 

Eastern Ontario system 5,338,1 15 . 82 

Thunder Bay system. . . 3,104,669.25 

Northern Ontario properties 625,282 . 56 

Nipissing rural power districts and Manitoulin rural power district 7,559.71 

Service building and equipment 706,848 . 99 

Bonnechere storage 3,536 . 97 

Hydro-Electric Railways (Guelph) 121,481 . 78 

Insurance, workmen's compensation and staff pensions 4,322,861 .69 

Total reserves of the Commission $69,433,260 . 25 

Total reserves of municipal electric utilities 59,736,819.76 



Total Commission and municipal reserves $129,170,080 .01 



As has been commented above in connection with the statement of revenues, 
the total reserves of the Commission increased in 1933 by $3,287,773.64 over the 
total for 1932, which was $66,145,486.61. The fact that the net increase in 
total reserves was, in 1933, less than in some former years, reflects the advan- 
tageous working out of the Commission's policy of cost stabilization, under 
which withdrawals were made in 1933 from special reserves provided out of 
revenues of earlier years for that purpose. The net increase in the total of 
Commission and municipal reserves for the year was $6,399,976.10. 

The consolidated balance sheet of the municipal electric utilities, on page 
288, shows a total cash balance of $1,696,489.24, and bonds and other invest- 
ments of $2,163,785.20. The total surplus in the municipal books now amounts 
to $41,612,778.64 in addition to depreciation and sundry other reserves 
aggregating $18,124,041.12 ; these two amounts making the total of $59,736,819.76 
shown in the above table. 

The following is a brief summary of the principal operations relating to 
the several systems of the Commission : 

Niagara System 

The Niagara system embraces all territory lying between Niagara Falls, 
Hamilton and Toronto on the east and Windsor, Sarnia and Goderich on the 
west served with electrical energy generated at plants on the Niagara and Ottawa 
rivers, supplemented with purchased power transmitted from plants on the 
Niagara, Gatineau, St. Lawrence, Ottawa and Lievre rivers. A few munici- 



1934 HYDRO-ELECTRIC POWER COMMISSION xiii 

palities and districts of the Niagara system are served also with power developed 
at DeCew Falls near St. Catharines. 

Arrangements for .progressive delivery of increased quantities of power, 
made some years ago, will furnish power supplies for this system, which, with a 
moderately rapid return to normal business conditions, should be adequate for 
the immediate future. In addition to power contracted for with the Gatineau 
Power Company, and power obtained from the development at Chats Falls 
which provides the Commission with 192,000 horsepower, the Commission holds 
contracts for the delivery of additional power, amounting eventually to 250,000 
horsepower, to be developed on the St. Lawrence river by the Beauharnois Light, 
Heat & Power Company, and 125,000 horsepower to be delivered to the Com- 
mission as required from a plant on the Lievre river under a contract with the 
James MacLaren Company, Limited, subsequently assigned to a subsidiary power 
company known as MacLaren-Quebec Power Company. The first block of 
20,000 horsepower to be taken under the contract with the MacLaren-Quebec 
Power Company was taken July 1, 1933, and the second block of power to be 
taken from the Beauharnois Light, Heat & Power Company, amounting to 
40,000 horsepower, was taken October 1, 1933. 

The total capital invested by the Commission on behalf of the co-operating 
municipalities of the Niagara system amounts to $208,143,427.49. This amount 
includes the investment in the power properties purchased from the Dominion 
Power and Transmission Company (which have been merged with, and now form 
part of the Niagara system), also the Commission's share of the generating plant 
at Chats Falls, together with the transformer and switching stations at that 
point and the transmission lines from the Ottawa river to the Niagara system. 
The accumulated reserves for renewals, obsolescence, contingencies and sinking 
fund, aggregate $52,380,601.09. 

From the rural power districts of this system, which are directly operated 
by the Commission, the revenue received for the year from customers was 
$2,063,70.73, and the total cost of supplying the service was $2,105,625.98, 
leaving a balance of $42,255.25, which has been charged to the districts in this 
system. 

With respect to the electric utilities of the various urban municipalities of 
the Niagara system, the cost of power, as adjusted by the Commission at the 
close of the year was $246,061.75 more than the total amount collected at the 
interim rates and this sum has been charged to the municipal utilities. The 
total revenue of the municipal electric utilities served by this system was 
$25,024,438.69. 

After meeting all expenses in respect of operation — including interest — setting 
up the usual standard depreciation reserve (which amounted to $1,604,015.63) 
and providing $2,108,108.41 for the retirement of instalment and sinking-fund 
debentures, the total net shortage for the year for the municipal electric utilities 
served by the Niagara system amounted to $652,392.31. 

Georgian Bay System 

The territory served by the Georgian Bay system includes that portion of 
the Province adjacent to Georgian bay and lake Simcoe. The area extends 

Errata — The total reserves in text of page xii should be 
the same as the totalled details, namely, $129,170,080.01. 

The revenue figure in third paragraph on page xiii should 
be $2,063,370.73 as on page xi. 

The figure of net increase in next to last line of second 
paragraph on pagex should be $3,287,773.64 as shown in third 
paragraph of page xii. 



xiv TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

from Huntsville in the north to Port Perry in the southeast, and on the west 
and north it is bounded by lake Huron and Georgian bay. It thus takes in the 
counties of Bruce, Grey, Dufferin, and Simcoe, and the northern portions of the 
counties of Huron, Wellington and Ontario, as well as a large portion of the 
district of Muskoka. The territory served by this system lies immediately north 
of the Niagara system and west of the Eastern Ontario system. 

During the year the distribution system purchased from The Mildmay 
Electric Company in the village of Mildmay, was sold to the Corporation and a 
cost contract executed with the latter for a supply of power under the Power 
Commission Act. The property purchased from The Formosa Electric Light 
Company last year was reconstructed and merged into the Bruce rural power 
district. 

Electrical energy for the Georgian Bay system is obtained from eleven 
hydro-electric generating plants at South Falls, Hanna Chute, and Trethewey 
Falls on the south branch of the Muskoka river, at Bala on the Muskoka river, 
at Wasdells Falls and Big Chute on the Severn river, at Eugenia Falls on the 
Beaver river, and at Hanover, Walkerton and Southampton on the Saugeen 
river. The output of these generating plants is supplemented by the purchase of 
power from the Niagara system, delivered through frequency changer equipment 
at Hanover and Mount Forest. 

Load conditions in the various municipalities of the system remained 
practically constant throughout the year in comparison with previous year 
conditions, although some new load was secured in one of the municipalities during 
the latter part of the year. The power supplied to summer resort districts forms 
an important part of the Georgian Bay system load, and the peak demand of this 
class of business was considerably greater than during last year, although it dees 
not show up in the yearly average due to the fact that it is all supplied during 
the summer months only. 

The lack of rainfall during the summer and fall months of the year seriously 
affected the stream flow of the rivers on which the various developments are 
situated, necessitating the purchase of a larger block of power from the Niagara 
system, than was purchased last year. 

The total capital invested by the Commission on behalf of the co-operating 
municipalities in the Georgian Bay system is $8,394,645.25 and the accumulated 
reserves for renewals, obsolescence, contingencies, and sinking fund aggregate 
$2,822,302.39. 

The revenue received from consumers in the rural power districts of this 
system directly operated by the Commission was $236,399.48 and the total cost 
of supplying service to same was $266,340.01, leaving a balance of $29,940.53 
to be charged to these districts, as detailed under financial statements in Section 
IX of this Report. 

The actual cost of power supplied by the Commission during the year to 
the electric utilities of the various urban municipalities of the Georgian Bay 
system served under cost contracts was $55,972.57 less than the total collections 
under the interim rates. This sum has been credited to the various municipalities 
directly affected. The total revenue of the municipal electric utilities served by 
this system was $1,135,255.35, a decrease of $18,366.96 as compared with the 
previous year. 



1934 HYDRO-ELECTRIC POWER COMMISSION xy 

After meeting all operating expenses and fixed charges, including interest, 
and the standard depreciation reserve amounting to $71,460.00, as well as pro- 
viding $59,232.44 for the retirement of instalment and sinking fund debentures, 
the combined municipalelectric utilities of the Georgian Bay system show a net 
loss for the year of $2,454.88. 



Eastern Ontario System 

This system serves that part of Ontario lying east of the areas served by 
the Georgian Bay and Niagara systems. The districts included are the Central 
Ontario, St. Lawrence, Rideau, Ottawa and Madawaska. 

Power is supplied from developments owned by the Commission on the 
Trent Canal system, the Mississippi and Madawaska rivers. Power is purchased 
from the Gatineau Power Company, the Rideau Power Co. and the Beach Estate 
at Iroquois. The Cedar Rapids Transmission Company has also been supplying 
power to the Commission during the year but notice was given of cancellation of 
this contract on December 31, 1932. No other major changes were made in 
generation or transmission facilities during the year. 

All the municipal distribution properties forming part of the old Electric 
Power Company properties have now been sold to the municipalities concerned, 
with the exception of the plants in Millbrook, Newburgh, Newcastle and Orono 
and the gas plant in Cobourg. The municipality of Orono has entered into 
negotiations with this Commission for the purchase of the local distribution 
system. 

While the power demands of this system are somewhat less than last year, 
the amount of purchased power from the Gatineau Power Company and other 
private companies has been very necessary owing to the shortage of power 
occasioned by the low water on the Trent river. 

The total capital invested by the Commission on behalf of the co-operating 
municipalities amounts to $19,372,833.44 and the accumulated reserves for 
renewals, obsolescence, contingencies and sinking fund aggregate $5,338,115.82. 

The rural power districts of this system, which are directly operated by 
the Commission, show the revenue received for the year from customers as 
$470,228.73 and the total cost of supplying service to be $503,110.95, leaving a 
balance of $32,882.22, which was charged to the districts in this system. 

With respect to the electric utilities of the various urban municipalities of 
the Eastern Ontario system operating under cost contracts, the actual cost of 
power supplied by the Commission during the year was $35,131.42 less than the 
total amount collected at the interim rates and this has been credited to the 
municipal utilities. The total revenue of the municipal electric utilities served 
by this system was $3,142,850.15, a decrease of $35,906.10 

After meeting all expenses in respect of operation — including interest — 
setting up the usual standard depreciation reserve (which amounted to 
$176,758.10) and providing $130,523.35 for the retirement of instalment and 
sinking-fund debentures, the total net surplus for the year for the municipal 
electric utilities served by the Eastern Ontario system amounted to $82,632.61. 



xvi TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Thunder Bay System 

The territory served by the Thunder Bay system lies wholly within the 
district of Thunder Bay, practically all of the power being utilized by the cities 
of Port Arthur and Fort William, and the rural sections immediately adjacent 
thereto, and by the village of Nipigon. 

Power is obtained from two hydro-electric developments on the Nipigon 
river, one at Cameron Falls and one at Alexander, and, in addition to supplying 
the domestic and commercial requirements of the municipalities mentioned, is 
used largely by the pulp and paper industry and the grain trade. A marked 
improvement has taken place in the load supplied on this system, especially 
during the latter portion of the year, due principally to the increased production 
by the pulp and paper mills, and also to an extensive use of secondary power 
sold on an "at-will" basis for the generation of process steam. Contracts already 
negotiated for the latter class of load, plus power sold on a firm power basis, 
will, during the coming year, require the entire generating plant capacity of the 
two developments serving this system. The total investment of the Commission 
in the Thunder Bay system is $18,630,772.18, and the accumulated reserves for 
renewals, contingencies and sinking fund amount to $3,104,669.25. 

From the rural power districts of this system, which are operated directly 
by the Commission, the revenue received for the year from customers was 
$9,275.86, and the total cost of supplying the service was $12,474.16, leaving a 
balance of $3,198.30, which has been charged to the districts in this system. 

The cost of power supplied by this system during the year was $95,683.25 in 
excess of revenue obtained from the interim monthly billing. This represents a 
substantial improvement over last year's conditions. A much better showing 
will be made during the next year when the new contracts previously referred to 
will be in operation for the full twelve months of the year. The total revenue 
of the municipal electric utilities in this system was $1,325,297.69. The munici- 
palities served by this system operated with a net loss of $54,796.75 after meeting 
all operating expenses — including interest — and setting up the standard deprecia- 
tion reserve amounting to $42,481.14 and providing $21,454.89 for the retirement 
of installment and sinking fund debentures. 



Manitoulin Rural Power District 

This rural power district supplies electrical service to the area surrounding 
the town of Gore Bay and the hamlet of Mindemoya. Other sections of Mani- 
toulin island, including the town of Little Current, the village of Manitowaning 
and the hamlet of Shequiandah and adjacent areas, have also made application 
for service, and various meetings were held for the purpose of submitting informa- 
tion to the communities mentioned. A complete investigation was made with 
respect to extending lines, and obtaining a supply of power from an additional 
source for this new load. 

At the present time the district is supplied with power purchased from the 
Kagawong development of the Little Rapids Pulp Company. 



1934 HYDRO-ELECTRIC POWER COMMISSION xvii 

Northern Ontario Properties 

The area in which are situated the Northern Ontario Properties comprises the 
entire portion of the Province lying north of lake Nipissing and French river 
areas, and west of the Quebec boundary, exclusive of the territory served by the 
Thunder Bay system. The active districts in which power is actually being 
delivered by the Commission include North Bay and the vicinity, in the district 
of Nipissing; Sudbury, and the vicinity in the district of Sudbury; Iroquois Falls 
in the district of Cochrane, and the Red Lake mining camp in the district of 
Patricia. These various districts are being served under a direct agreement with 
the Government of the Province. They are not interconnected, and are served 
under entirely different conditions than those prevailing in the southern and 
eastern portions of the Province. Many sections in the northern part of the 
Province are served by independent municipal utilities, and the Commission, 
during the year, has, upon request, given engineering advice and assistance 
concerning the operation and maintenance of the local systems, to many of 
these utilities. 

Nipissing District 

The area served in this district includes the city of North Bay, the town of 
Powassan and the unincorporated hamlets of Callander and Nipissing and 
portions of the townships of Ferris, Himsworth, Nipissing and Widdifield. 
Power is obtained from hydro-electric developments at Nipissing, Bingham 
Chute and Elliott Chute on the South river, supplemented when necessary by 
purchased power from the Abitibi Power and Paper Company's development at 
Crystal Falls on the Sturgeon river. 

Very little change occurred in the demands of this district throughout the 
year, compared with the previous year; consequently, no generating plant, 
transformation or transmission changes other than those of a routine nature were 
required. 

Sudbury District 

This district includes the area adjacent to the city of Sudbury which is 
served at 60 cycles from three power developments on the Wanapitei river. 
Power is supplied for municipal and lighting purposes to the city of Sudbury, and 
to large mining companies in the Sudbury basin. A substantial increase in load 
has taken place on this system during the year, due to one of the large mining 
companies having increased its demand by approximately 50 per cent, in conse- 
quence of which the plant capacity of the developments is completely sold, and 
any further load expansion will have to be taken care of at 25 cycles from the 
Abitibi Canyon transmission line system, or by t^e installation of frequency 
changer sets for transformation from 25 to 60 cycles. 

Abitibi District 

This district embraces that section of the Province within transmission 
distance of the Abitibi Canyon development and includes the mining areas 
adjacent to Sudbury, Timmins and Kirkland Lake. During the year the Com- 
mission assumed, on behalf of the Government of the Province, the operation of 
the Abitibi Canyon development and transmission line system formerly the 
property of The Ontario Power Service Corporation Limited. Power is being 
supplied at the present time to a large mining industry at Copper Cliff and nego- 



xviii TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

tiations have been carried on with a number of mining companies in the Porcupine, 
Kirkland Lake and Swayze camps, and it is anticipated that a number of these 
companies will be supplied during the coming year. A contract was completed 
with The Canada Northern Power Corporation for supplying all of the future 
load growth of this company for a term of ten years. 

Patricia District 

This district comprises the territory included in that portion of the Province 
lying within the geographical area bearing the same name. At the present time 
the Commission in this district is operating one power development only. It is 
situated at the foot of Lac Seul on the English river and power is being supplied 
to a large gold mine in the Red Lake mining camp. Power is available for any 
other mining property within transmission distance of this development. A 
large increase in the load on this development has taken place during the year, 
due to the mining company served having substantially increased its milling 
capacity. The total load, averaged over the year, shows an increase of 3 per cent, 
but the load during the latter part of the year was gradually increasing. The 
peak load, occurring in October, shows an increase of 28 per cent over the previous 
year. 

A survey was made and an estimate prepared in connection with a develop- 
ment on the Albany river at the foot of lake Joseph for two other mining properties 
in the Patricia district. It is expected that contracts will be closed early next 
year, and arrangements made to proceed with the construction of this 
development. 

The Annual Report 

The Table of Contents, pages xxv and xxvi, conveys a good understanding 
of the scope of the matters dealt with in the Report, to which there is also a 
comprehensive Index. To those not conversant with the Commission's Reports 
the following notes will be useful. 

In Section II, pages 5 to 60. dealing with the Operation of the Systems, 
are a number of interesting diagrams showing, graphically, the monthly loads 
on the various systems. Tables are also presented showing the amounts of 
power taken by the various municipalities in October during the past three years. 

The rural distribution work of the Commission has proved of widespread 
interest and special reference to this is made in Section III, on pages 69 to 88. 
The power distributed to rural districts is, and possibly must always be, but 
a relatively small proportion of the power distributed by the Commission. The 
supplying of electrical service in rural areas, and especially on the farm, has, 
however, been of great economic benefit to Ontario. The Provincial Government 
grants-in-aid of the capital cost of this work have been of value to agricultural 
activities, and have assisted the Commission to extend rural transmission lines 
to many areas. 

In Sections IV, V and VI will be found information respecting progress of 
work on new power developments and on transmission system extensions, 
together with photographic illustrations. 

About one-half of the Report is devoted to financial and other statistical 
data which are presented in two Sections, IX and X. 



1934 HYDRO-ELECTRIC POWER COMMISSION xix 

Section IX presents in summary form the financial statements relating to 
the operations of the Commission chiefly in the generation, transformation and 
transmission of electrical energy to the co-operating municipalities. It is 
introduced by an important explanatory statement which appears on pages 
133 to 137, to which special reference should be made. 

Section X presents in summary form the financial statements relating to 
the operations of the municipalities in the localized distribution of electrical 
energy to consumers. It also contains details of the costs of electrical energy to 
consumers in the various municipalities and tabular statements of the rates in 
force which have produced these costs. An explanation of the various tables 
and statements is given at the commencement of this Section on pages 281 to 283, 
and a special introduction to Statement "D," which relates to the cost of 
electrical service in Ontario, together with a diagram, appears on pages 406 to 409. 

In its Annual Reports the Commission aims to present a comprehensive 
statement respecting the activities of the whole undertaking under its 
administration. Explanatory statements descriptive of the operations of the 
Commission in various branches of its work are suitably placed throughout 
the Report in order that the citizens of the Province may be kept fully 
informed upon the working-out of the Commission's policies. 

The Commission receives many letters asking for general information 
respecting its activities, as well as requests for specific information concerning 
certain phases of its operations. In most cases these enquiries can satisfactorily 
be answered by simply directing attention to information presented in the 
Annual Report of the Commission. Real benefit would result to the ''Hydro" 
undertaking if those who are commenting upon aspects of the Commission's 
work would first make sure by consulting the Commission's publications that 
the data upon which their comments are to be based are adequate and pertinent 
to the subject in hand. By such a course much misrepresentation, as well as 
inconvenience, would be avoided. 



In closing this summary of the record of Hydro's progress during the past 
year, and at a time when we are emerging from a period of exceptional economic 
stress, it is especially fitting to acknowledge the devotion and efficiency that 
characterize the services rendered by the Commission's staffs. Unquestionably, 
in both good times and bad times, the municipall^owned Hydro undertaking 
owes in great measure its outstanding success to the unremitting and competent 
efforts of the professional and other employees of the Commission and of the 
municipal utilities, directed as such efforts are towards the constant improvement 
of the technical operations of the undertaking. The Commission, as trustee 
charged with providing electrical service for Ontario citizens at minimum costs, 
has not given its employees remuneration as large as is paid by comparable 
privately-owned electrical utilities elsewhere, but the Commission has felt that 
the least it could do in appreciation of the loyalty of its employees was to give 
them assurance that their security of employment was not subject to arbitrary 
disturbance. Moreover, continuity of service by a competent staff — a source 
of strength to any business organization — is, in the case of the Commission's 



xx TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

undertaking with its many unique features and its principle of service at cost, 
especially necessary. With these considerations in mind, the Commission some 
years ago established a system of contributory pensions, under which the 
permanent employees deposit with the Commission sums, which the Commis- 
sion supplements, in order that the employees may have security in old age after 
a lifetime of faithful service. 

The harmonious relations that have always existed between the Commission 
and its staff have been greatly promoted by the attitude taken by successive 
Provincial governments toward maintaining the independence of administration 
of the Commission as a business enterprise operated in trust for the municipalities. 
The basic principles established by the founders of the undertaking, and incor- 
porated in the Power Commission Act, give the Commission sole jurisdiction 
over appointments of staff and all other details of operation, and limit govern- 
ment participation in the municipal undertaking to approval of such matters 
as capital expenditures and power contracts determined by the Commission to 
be required in the interests of the municipalities. 

It is a matter of sincere satisfaction to me, speaking after more than a decade 
of service as Commissioner, and, latterly, as Chairman, to be able to affirm 
categorically that at no time in my term of office has any Ontario Government 
gone beyond the limits of jurisdiction assigned to it by the Power Commission 
Act as appropriate to its function of banker for the municipalities. There has 
been no suggestion of interference with appointments of employees or other 
matters that are in the exclusive jurisdiction of the Commission. Moreover, 
every capital expenditure and every power commitment on behalf of munici- 
palities has been made at the instance of the Commission having regard only 
to the interests of the municipalities, and the Government's participation in 
such matters has been confined to scrutinizing and approving the Commission's 
proposals, and assisting in inter-governmental negotiations where necessary. 
The readiness of successive Governments to co-operate has been of notable 
value to the undertaking; in the case of rural service the Governmental financial 
contribution is a factor without which the remarkable expansion in service in 
recent years could not have been achieved. I am constrained to record these 
observations here because of the fact that statements intimating the contrary 
have been publicly but unjustifiably made. 

The co-operation manifested by the Press in giving space and services to 
inform the citizens of Ontario on matters relating to the Commission's work is 
a valuable safeguard to the welfare of the Hydro undertaking, and the Com- 
mission desires again to record its special appreciation of the public-spirited 
support accorded to its efforts. 

Confirming the Commission's announcement, made early in the present 
year, of its expectation of an improvement in the general adverse conditions 
against which the Hydro undertaking has had to contend for the last three or 
four years, it is a gratification to be able, at the time of writing, to state that 
results thus far evident for 1934 are showing a very substantial betterment 
over the results for corresponding periods of 1933. The large increases in electrical 
demands and in revenues that are being experienced afford excellent encourage- 



1934 HYDRO-ELECTRIC POWER COMMISSION xxi 

ment. The Commission is confident that, with continuation of present trends, 
the results of operation of the Hydro undertaking in the next two or three years 
will furnish complete vindication of the wisdom of the actions it has taken with 
respect to providing power supplies adequate for the requirements in the early 
future of the municipalities and industries. 

Respectfully submitted, 

J. R. Cooke, 

Chairman. 



1934 HYDRO-ELECTRIC POWER COMMISSION xxiii 



Toronto, Ontario, March 31st, 1934. 



Hon. J. R. Ccoke, M.L.A., 



Chairman, The Hydro-Electric Power Commission of Ontario, 
Toronto, Ontario. 

Sir, — I have the honour to transmit herewith the Twenty-sixth Annual 
Report of The Hydro-Electric Power Commission of Ontario for the fiscal year 
ended October 31st, 1933. 

I have the honour to be, 

Sir, 
Your obedient servant, 

W. W. Pope, 

Secretary 



934 HYDRO-ELECTRIC POWER COMMISSION xxv 



CONTENTS 

Section page 

I. Legal Proceedings: 

Acts (see also Appendix I) ------------ l 

Right-of-way --------------- 2 



II. Operation of the Systems: 

General -5 

Niagara system 14 

Georgian Bay system 29 

Eastern Ontario system - 36 

Thunder Bay system - 48 

Northern Ontario properties 52 



III. Municipal Work: 

Niagara system 61 

Georgian Bay system 64 

Eastern Ontario system - - 65 

Thunder Bay system 66 

Northern Ontario properties - - - - 67 

Rural Electrical Service 69 



IV. Hydraulic Engineering and Construction: 

General 89 

Niagara system 90 

Georgian Bay system - 91 

Northern Ontario properties 92 

Hydraulic investigations - 96 



Electrical Engineering and Construction: 

♦ 

Niagara system 99 

Georgian Bay system 102 

Eastern Ontario system ----- 104 

Thunder Bay system - 104 

Northern Ontario properties 106 



VI. Transmission, Distribution and Rural systems (see also Appendices II and III): 

Niagara system 107 

Georgian Bay system 108 

Eastern Ontario system - - 108 

Thunder Bay system 108 

Telephone lines — all systems - - - - - - - - - - 110 

Distribution lines and systems - - - - - - - - - - 110 



xxvi TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Section page 

VII. Laboratories 113 

Electricai Inspection - 125 



VIII. Electric Railways: 

Sandwich, Windsor and Amherstburg railway ------- 128 

guelph district railway - 130 



IX. Financial Statements re Hydro-Electric Power Commission: 

Explanatory statement respecting the accounts - 133 

General detailed statement of assets and liabilities 138 

Niagara system 154 

Georgian Bay system 212 

Eastern Ontario system 234 

Thunder Bay system 258 

Provincial Treasurer, account with 264 

Northern Ontario properties 266 

Guelph Radial railway 272 

Hamilton Street railway 274 

Appropriations, advances and capital expenditures 276 



X. Municipal Accounts and Statistical Data: 

Explanatory statement 281 

Consolidated balance sheet 284 

Consolidating operating report 289 

Statement A — Balance sheets 294 

Statement B — Detailed operating reports 340 

Statement C — Respecting street lights - 387 

Statement D — Comparative revenue, consumption, number of consumers, 

AVERAGE MONTHLY BILL, NET COST PER KILOWATT-HOUR, ETC. - - - 406 

Statement E — Cost of power to municipalities and rates to consumers for 

DOMESTIC, COMMERCIAL LIGHTING AND POWER SERVICE 424 



Appendix I. Acts -. 441 

Appendix II. Transmission Line Records 445 

Appendix III. Distributing Lines and Systems 468 

Index 475 



1934 HYDRO-ELECTRIC POWER COMMISSION 



ILLUSTRATIONS 

PAGE 

Abitibi Canyon Power Development ---------- Frontispiece 

Forestry Division — Operating Department: 

Diseased trees a menace ------------- 1 j 

Crown and side pruning - - - - - - - - - - - - - -13 

Rural Electrical Service in Ontario: 

Cheese factory utilising electric power - - - - - - - - -69 

a farm home in ontario using hydro service 70 

Suggested set-up of utility-motor chopper in barn - - - - - - -74 

mllk cooling by electric refrigeration with agitation 75 

Electric soil heating 79 

Three-horsepower motor driving machinery in barn - 80 

Application of electric drive to water pumping 81 

Walkerton Dam — Saugeen River ------------ 91 

Abitibi Canyon Power Development — Abitibi River: 

forebay, dam and sluice-gate ------------ 92 

High-water channel - - -93 

Tailrace from power house -93 

Kagami Falls — Albany River - 97 

Electric Steam Generators — Ontario Paper Company 101 

Transformer Station — Ontario Paper Company - - 103 

Transformer Station at Cameron Falls — Nipigon River - 105 

Hydro 220,000-Volt Transmission Lines: 

Transposition towers, Beauharnois-Chats Falls Line* - - - - - - 109 

Semi-anchor tower -------- 109 

Suspension tower --------------- 309 

Testing and Research Laboratories: 

Field inspection of concrete structures - - - 115 

Apparatus for measuring the gloss of paints - - - 117 

Endurance test on thermostats - - - - - 119 

Laboratory for testing insulated wire conductors - - 120 

Brake TESTS on small motors - - - - 121 

Temperature and overload tests on fuses - 121 

Endurance tests on three-heat range switches - - - - "- - - 124 



xxviii TWENTY-SIXTH ANNUAL REPORT No. 26 



DIAGRAMS 

PAGE 

Niagara system — Peak loads, 1910 to 193? ---------- 16 

Niagara system — Total kilowatt-hour load, 1919 to 1933 ------ \g 

Dominion Power and Transmission system — Diagram of stations ----- 23 

Niagara system — Diagram of stations. Insert facing ------- 24 

Georgian Bay system — Peak loads, 1919 to 1933 --------- 31 

Georgian Bay system — Diagram of stations. Insert facing ------ 32 

Eastern Ontario system — Peak loads for all districts ------- 37 

Precipitation diagram — Otonabee watershed -------- 38 

Central Ontario district — General operating data ------- 39 

Ottawa district — Peak loads, 1917 to 1933 --------- 43 

Madawaska district — Diagram of stations --------- 44 

Eastern Ontario system — Diagram of stations. Insert facing ----- 44 

Thunder Bay system — Peak loads, 1921 to 1933 --------- 49 

Thunder Bay system — Diagram of stations ----- 51 

Northern Ontario Properties — Diagram of stations -------- 53 

Nipissing district— Peak loads, 1921 to 1933 -------- 52 

Sudbury district — Peak loads, 1930 to 1933 --------- 55 

Abitibi district — Peak loads, 1931 TO 1933 --------- 57 

Patricia district — Peak loads, 1930 to 1933 --------- 59 

Rural power districts — Mileage of primary lines approved - - - - - - 76 

Aggregate peak loads, 1921 to 1933 ----------- 77 

Abitibi Canyon power development — Diagram of works - ----- - 94 

Rural power districts — Diagram illustrating growth of - - - - - --111 

Electrical inspection department — Chart illustrating operations - - - - 126 

Sandwich, Windsor and Amherstburg Railway — Operating statistics - - - - 129 

guelph district railways — operating statistics - - - - - - - -' 131 

Cost of electrical service in Municipalities served by The Hydro-Electric Power 

Commission ----------- 407 



MAP 

Transmission lines and stations of The Hydro-Electric Power Commission of 

Ontario -------------- At end of volume 



TWENTY-SIXTH ANNUAL REPORT 

OF THE 

Hydro - Electric Power Commission 

of Ontario 



SECTION I 



LEGAL 

AT the 1933 Session of the Legislative Assembly of the Province of Ontario, 
three Acts relating to the work of the Hydro-Electric Power Commission 
of Ontario were passed. These are reproduced in full in Appendix I to this 
report. The short titles to the said Acts are as follows: 

The Power Commission Act, 1933, Chapter 47. 

The Abitibi Canyon Power Development Act, 1933, Chapter 1. 

The Manitoulin Rural Power District Act, 1933, Chapter 28. 

The agreements between the Hydro-Electric Power Commission of Ontario 
and the municipalities and corporations mentioned in the list hereunder given 
were approved by Order-in-Council dated the 9th day of February, 1934. 

Villages Townships 

Colborne Dec. 12, 1932 Carrick * Nov. 14, 1932 

Mildmay Nov. 30, 1932 Drummond Sept. 5, 1933 

Oso Nov. 1, 1932 

Sarawak Feb. 1, 1933 

Verulam Mar. 6, 1933 

Corporations 

American Cyanamid Company Nov. 19, 1932 

Falconbridge Nickel Mines Limited Feb. 9, 1933 

Firestone Tire & Rubber Company of Canada Limited Nov. 1, 1932 

His Majesty The King, in the right of the Province of Ontario (re'Mimico Asylum) . . . Aug. 1, 1932 
His Majesty The King, in the right of the Province of Ontario (re Ontario Reforma- 
tory) Aug. 1, 1932 

Interlake Tissue Mills Co. Limited Sept. 11, 1933 

[i] 

1 — H.E 



2 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Corporations — Continued 

The International Nickel Company of Canada Limited and The Huronian Company 

Limited Dec. 23, 1932 

National Trust Company Limited, Receiver and Manager of Great Lakes Paper 

Company Lim ited June 14, 1933 

Northern Empire Mines Company Limited May 27, 1933 

Page-Hersey Tubes Limited Jan. 30, 1933 

Provincial Paper Limited July 19, 1933 

Provincial Paper Limited Sept. 1, 1933 

Strathcona Paper Company Limited Jan. 1, 1933 



Right-of-Way 
Rural Power Lines 

Wood-pole lines and extensions were constructed in the following rural 
power districts during the year: Alexandria, Amherstburg, Aylmer, Ayr, Baden, 
Bala, Barrie, Baysville, Beamsville, Beaumaris, Beaverton, Belleville, Bowrnan- 
ville, Brant, Brockville, Bruce, Caledonia, Chatham, Chesterville, Clinton, 
Cobourg, Colborne, Delaware, Drumbo, Dundas, Elmira, Essex, Fenelon Falls, 
Fort William, Gait, Georgetown, Grantham, Guelph, Hawkestone, Huntsville. 
Ingersoll, Iroquois, Kemptville, Keswick, Kingston, Kingsville, Lakefield, 
Lindsay, London, Manitoulin, Markdale, Markham, Martintown, Maxville, 
Millbrook, Napanee, Nepean, Newcastle, Newmarket, Norwood, Orangeville, 
Oshawa, Owen Sound, Perth, Peterborough, Petrolia, Port Arthur, Prescott, 
Preston, Renfrew, St. Marys, St. Thomas, Simcoe, Smiths Falls, Sparrow Lake, 
Stirling, Strathroy, Streetsville, Tara, Thamesville, Trenton, Wallaceburg, 
Walsingham, Waterdown, Waterford, Welland, Wellington, Williamsburg, 
Woodbridge, Woodstock. 

The practice, as in the past, has been to construct these lines on public 
highways or roads where at all possible, but in a few cases, owing to local con- 
ditions and the desire to avoid cutting trees, it has been found advisable to 
place the lines on private property. In such cases the necessary right-of-way 
has been acquired and compensation made for tree trimming or cutting. 

There have also been a number of cases where, owing to road improvement 
work being carried out by the Department of Public Highways or County Road 
Commissions, it has been found necessary to change the location of existing pole 
lines. In all such cases satisfactory arrangements have been made with the 
department or commission having control of the roads in question. 

High and Low Tension Wood-Pole Lines 

Construction work has been carried out on the following high- and low- 
tension wood-pole lines, and the necessary rights-of-way and tree trimming 
rights have been secured during the year: 

Trenton to Belleville. Port Hope to Newcastle. 

Colborne to Cobourg. Bowmanville to Oshawa. 

Auburn to Lakefield. Napanee to Bath. 

Oshawa to Toronto. Delora to Marmora. 

Norwood to Havelock. Smithville to Stoney Creek. 

Warkworth to Newcombe. Burlington to National Fire Proofing Junc- 

Newcombe to Welcome. tion. 

Welcome to Oshawa. Kilsyth to Derby Mills. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



High and Low Tension Wood-Pole Lines — Continued 



Walkerton to Mildmay. 

Durham to Mount Forest. . 

Meaford to Collingwood. 

Kilsyth to Owen Sound. 

Melancthon to Amaranth. 

Fraxa to Orangeville. 

Ragged Rapids to Bala. 

Erbs Junction to Hanover. 

Cornwall to Winchester. 

Williamsburg to Winchester. 

Lynn to Athens. 

Winchester to Cardinal. 

Dominionville to Alexandria. 

Utterson to Huntsville. 

Dominion Junction to Maxville. 

Utterson to Windermere. 

Muskoka Beach Junction to Muskoka Beach, 

Windermere to Rosseau. 

Dundas to Caledonia. 

London to St. Thomas. 

Guelph to Preston. 

Kitchener to Stratford. 

Kitchener to Waterloo. 

Stratford to Sebringville. 

Glengarry Junction to Glengarry Distributing 

Station. 
Woodstock to Dufferin. 
Woodstock to Beachville. 
St. Thomas to Kent. 
St. Thomas to Sarnia. 
Brant to Brantford. 
Brant to Paris. 
Paris to Ayr. 
Ayr to Drumbo. 

Cooksville to York Transformer Station. 
Kent to Essex. 
Winchester to Williamsburg. 
St. Jacobs Distributing Station to Elmira. 
Essex to Maidstone. 
York Transformer Station to Weston. 
York Transformer Station to New Toronto. 
Wiltshire Avenue to Weston. 



Kitchener Transformer Station to Erbs 
Junction. 

Welland to Port Colborne. 

Erbs Junction to Stratford. 

Fletcher to Tilbury. 

Lythmore to DeCewsville. 

Dundas to Binkley's Corners. 

Ontario Gypsum Company to Hagersville. 

York Mills to Newmarket. 

Danforth Junction to West Hill. 

Andrews Junction to Pottageville. 

Langstaff to Mount Joy. 

Dorchester Distributing Station to Dor- 
chester. 

Acton to Cheltenham. 

Ontario Agricultural College (Guelph) to 

Elora. 

Harbour Hill to Goderich. 

Sebringville to Milverton. 

Milverton to Listowel. 

Listowel to Palmerston. 

Harriston Junction to Harriston. 

Beachville to Embro. 

Norwich to Otterville. 

Mount Vernon to Burford. 

Paris to Burford. 

Brittania Junction to Streetsville. 

Tilbury Junction to Fletcher. 

Ridgetown to Rondeau. 

Prince Albert to Ridgetown. 

Como Junction to Dominion Sugar Company. 

Prince Albert to Como. 

Fletcher to Merlin. 

Leamington Junction to Leamington Dis- 
tributing Station. 

Kleinburg Distributing Station to Bolton, 

Arnprior to Galetta. 

Burnstown to Arnprior. 

Kirkfield Junction to Kirkfield Distributing 
Station. 

North Bay to Sturgeon Falls. 

Smoky Falls to North Bay. 



Substation Site 



A site for a substation in connection with the Markham rural power district 
was purchased during the year at Ringwood. 



220,000-Volt Lines 



The work of completing settlements for right-of-way, tree rights, damages, 
etc. has been carried on during the year on the Gatineau high-tension lines, 
and on the line between Chats Falls and Cumberland Junction, and between 
Cumberland Junction and the Inter-provincial Boundary. 



In a few cases where settlements could not be arrived at by negotiation, the 
owners have called upon the official valuator to file his award. These awards 
have been accepted by the owners in all cases, no appeals having been entered. 



TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 



General 



During the year the operation of the Brantford and Hamilton Electric 
Railway was discontinued, and as the right-of-way was no longer required, 
efforts were made to dispose of it to the owners of the adjoining lands. In a 
great majority of cases satisfactory arrangements have been made with such 
owners to take over this right-of-way. 

As the Commission was not successful in acquiring by negotiation the 
lands owned by the Kingdon Mining, Smelting & Manufacturing Company in 
the Township of Fitzroy, the matter was referred to the Ontario Municipal 
Board for arbitration. These arbitration proceedings were quite prolonged, 
involving sittings of the Board for forty-three days. The Board's award was 
finally filed, and has been accepted by both parties, and the matter has been 
closed. 

In a number of cases surplus lands not required by the Commission in 
connection with its works have been disposed of. 



934 HYDRO-ELECTRIC POWER COMMISSION 



SECTION II 



OPERATION OF THE SYSTEMS 



The past year's operation of the systems has been satisfactory. Few 
interruptions to service occurred, and failures of equipment were relatively 
few and not serious in extent. On June 7, 1933, a storm of extreme severity, 
accompanied by high winds, lightning and rain, caused damage in many districts 
between London, Toronto and Niagara Falls. Twelve steel towers collapsed 
during the storm, and damage was done to various low-tension lines, and to 
some of the station equipment connected to them, the total cost of repairs 
approximating $27,000. With this exception there were no failures of lines or 
apparatus which resulted in extensive disturbances to service. In another part 
of this section details will be found regarding such failures of equipment as 
occurred in the ordinary course of operation, together with an outline of the 
repairs made and the maintenance work carried out. 

The Eastern Ontario and Georgian Bay systems suffered from a lack of 
rainfall which reduced the stream flow and the capacity of the generating plants. 
On the Georgian Bay system the reduction in generating capacity was offset 
by an increased transfer of power from the Niagara system. On the Eastern 
Ontario system the low stream flow during certain periods reduced the capacity 
of all the generating stations on the Trent river to less than 40 per cent of their 
normal maximum capacity, and a severe power shortage would have been 
experienced if a supplementary reserve supply of power had not been available 
from the Gatineau Power Co. The Nipissing district ^so experienced a period 
of low precipitation, but the storage works constructed by the Commission 
made it possible for the stream flow to be maintained in volume adequate to 
enable the generating plants to supply the demand for power. 

It has been customary in this section of the Report to give a summary of 
load conditions. A load graph is given in connection with each system, showing 
the load month by month throughout the year, and extending back over a 
period of time depending on the age of the system and the records available. 
These graphs may be consulted for details regarding the load on each system, 
the following remarks dealing mainly with the total load of the Commission, 
that is, the combined load of the systems. 

In an enterprise as large as that of the Commission increases are apt to 
occur at one point while decreases occur at another point. Under such conditions 
broad generalizations cannot be expected to hold true in all cases, and to avoid 



6 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

any possibility of misunderstanding or appearance of inaccuracy, attention is 
called to the importance of treating the statements given herein as applying 
only to the combined total of the systems' load, or to that section of the load 
specifically referred to in the text. 

In the fiscal year ending October 31, 1933, the total load of the Commission, 
for all systems combined, amounted to 4,612.000,000 kw-hrs., exceeding that of 
1932 by 171,000,000 kw-hrs., as shown in the table of power generated and 
purchased given on the next page. 

Of more importance than this increase in the average load for the year, 
is the upward trend of load which became apparent during the latter half of 
the year. In last year's Annual Report reference was made to the reduction in 
load which had occurred during the depression. In that Report it was pointed 
out how the downward trend appeared in 1930 and continued throughout 1931, 
but in 1932 the rate of decrease was checked, the reduction for 1932 being only 
1.2 per cent as against a decline of 15 per cent during 1931. During the months 
of December, 1932, and January, 1933, there was a marked slump in the total 
load, to which a downward trend in the primary load and a loss of secondary 
load both contributed. In February a substantial block of secondary power 
was added, which very largely compensated for the decreases in both primary 
and secondary power during the previous months. In July a very substantial 
increase was made in both primary and secondary load, and further increases 
occurred during the succeeding months. 

During the last four months of the fiscal year 1933, the total load exceeded 
that of the corresponding months of the previous year by about 245,000,000 
kilowatt-hours. In consequence, the decreases during the earlier part of the 
year were more than off-set by the increases during the latter part of the year, 
and the complete year shows a net increase of 171,000,000 kilowatt-hours. 

In October, 1933, the total peak load of the Commission reached the high 
figure of 1,366,000 horsepower, an increase of 23 per cent over the corresponding 
month of the previous year. This is the highest load ever carried by the Com- 
mission, in any month, either before or since the beginning of the depression. 

The above figures should not be used as an indication of business conditions 
in the Province, or for the purpose of forecasting load during the coming year, 
without proper allowance for the quantity of secondary power included therein. 

"Secondary" power is a term applied to power which is sold subject to 
unlimited interruptions, to reduction or to complete withdrawal, at any time 
it is required for use by municipalities, or for the maintenance of the supply 
of firm power. During 1933, the Commission was able to effect the sale of large 
blocks of power on this basis, mainly for the generation of steam by electricity. 
Under these arrangements energy from Canadian water powers is utilized and 
replaces large quantities of imported coal. In connection with such use, it 
has not been necessary for the Commission to supply any additional generating 
equipment, and the power is still effective as a system reserve for "firm power" 
customers, and is available to meet their demands at any time. 

Recent developments in the sale of secondary power have made it necessary 
this year to present in a somewhat different manner the figures relating to 
certain power which has been sold for the purpose of steam generation. Prior 



1934 HYDRO-ELECTRIC POWER COMMISSION 7 

to 1930 the rapid growth of the Commission's loads had prevented the provision 
of a suitable amount of reserve capacity, and consequently the amount of 
secondary or off-peak power sold was relatively small. From October, 1930, 
to October, 1932, inclusive, a block of power was "resold" to the Gatineau 
Power Company to be used for steam generation. This transaction was reflected, 
in the statistics presented, in a reduction of the power purchased from the 
Gatineau Power Company, because it was the equivalent of a temporary and 
revocable reduction in capacity, and as at that time no secondary power was 
distributed in Ontario, it did not seem appropriate to include the contract 
power thus temporarily relinquished, as an addition to the system load figures. 
During 1933, in which year the sale of substantial quantities of secondary power 
began in Ontario, the resale to the Gatineau Power Company also recommenced. 
Since it is necessary to include Ontario's new load of secondary power in the 
figures for total load, and since the resale to the Gatineau Power Company 
represents secondary power which is similar both in the characteristics of being 
subject to immediate and unlimited interruptions and in the use to which it is 
put, it appears to be appropriate and necessary now to include this "resale" 
power in the figures for total load. In making comparisons, therefore, of certain 
loads for 1933 and for 1932 it has been necessary to show them both on the 
same basis and, in some cases, this has required revision in the 1932 figures to 
which attention has, herein, been directed. 

In general it is only industries consuming relatively large quantities of 
power which can utilize secondary power. During the past year the Commission 
has been in a position to offer sufficiently large blocks of power to make the 
use of this class of power attractive to certain industries, and since February, 
1933, the secondary load in Ontario, which was previously of negligible pro- 
portions, has been built up to an extent which materially affects the statistics 
for the total load. While it is hoped that this class of load will always be continued 
as a source of revenue from reserve generating capacity, it is subject to wide and 
irregular fluctuations according to load and business conditions, and should not 
be included in any study of the firm load trend, nor should it be included in 
any statistics of electric power consumption which are intended for use as an 
index of business conditions generally. The firm load is of a different nature 
and is generally regarded as an excellent business index, due to the fact that 
such power is used by so many of the factories, stores and residences throughout 
the districts served. It is not subject to the irregular fluctuations of secondary 
power. 

For the above reasons it is of interest to compare the Commission's firm 
load in Ontario during 1933 with that of the previous year, omitting all secondary 
and export power. 

In September and October, 1932, the firm load showed the usual seasonal 
increases. This continued during the month of November, 1932 (which forms 
the first month of the past fiscal year 1932-33). However, in December, 1932, 
the firm load showed a definite downward trend which continued until May, 
1933. This downward trend was more marked than the usual seasonal decline 
of load, which normally begins in February and continues until some time in 
August. 

In May, 1933, the downward trend terminated, and an upward movement 
commenced, which was of an even more marked character than the downward 
trend of the previous months. This upward trend continued consistently from 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



TOTAL POWER GENERATED AND 
HYDRO-ELECTRIC GENERATING PLANTS 



Generating plants 


Maximum 

normal 

plant 

capacity 

Oct. 31, 

1933, 

horsepower 


Peak load 

during 
fiscal year 
1932-1933 
horsepower 


Total output 

during 

fiscal vear 

1932-1933 

kilowatt-hours 


Niagara system 

Queenston-Chippawa — Niagara river. . . . 


500,000 
180,000 
150,000 

96,000 

50,000 
24,000 

5,600 

1,600 

2,300 

600 

5,800 

1,200 

7,800 

400 

500 

300 

4,500 
3,500 
7,000 
4,500 

10,500 
4,200 

15,300 
2,400 
1,000 
3,000 
400 
5,400 
1,100 

73,500 
50,000 

2,100 
1,200 
1,700 

5,900 
2,900 
7,500 

4,000 

55,000 


461,126 
119,303 

70,375 

94,504 
42,091 

6,011 

1,609 

2,145 

583 

5,791 

1,227 

7,614 

382 

503 



3,619 
1,810 
7,507 
4,625 
10,456 
3,150 
15,282 
1,984 

938 
3,117 

375 
1,588 

402 

48,700 
48,200 

2,366 
1,307 
1,910 

5,563 
2,882 
6,233 

2,627 

45,389 


1,834,328,000 


"Ontario Power" — Niagara river 


145,624,000 


"Toronto Power" — Niagara river 


64,521,000 


Chats Falls — Ottawa River (Commission's 




half) 


124,024,550 


Dominion Power and Trans, system* 

Decew Falls — Welland Canal 


97,082,300 


Steam Plant — Hamilton 


24,800 


Georgian Bay system 

South Falls — South Muskoka river 


20,495,760 


Hanna Chute — South Muskoka river 

Trethewey Falls — South Muskoka river 

Bala No. 1 and 2 — Muskoka river 


6,676,800 
8,925,600 
2,224,344 


Big Chute — Severn river 


16,396,920 


Wasdells Falls — Severn river 


3,403,240 


Eugenia Falls — Beaver river 


17,794,960 


Hanover — Saugeen river 


104,524 


Walkerton — Saugeen river 


1,307,100 


Southampton — Saugeen river. ... 





Eastern Ontario system 

Sidney-Dam No. 2 — Trent river 


7,826,700 


Frankford-Dam No. 5 — Trent river 


225,500 


Meyersburg-Dam No. 8 — Trent river 


11,160,530 


Hague's Reach-Dam No. 9 — Trent river 

Ranney Falls-Dam No. 10 — Trent river 


7,245,700 
13,937,820 


Seymour-Dam No. 11 — Trent river 


7,981,130 


Heely Falls-Dam No. 14 — Trent river 


20,118,400 


Auburn-Dam No. 18 — Otonabee river 


6,467,050 


Fenelon Falls- Dam No. 30-Sturgeon river 


1,410,300 


High Falls — Mississippi river ... 


4,263,720 


Carleton Place — Mississippi river 


11,848 


Calabogie — Madawaska river ... 


4,433,951 


Galetta — Mississippi river 


12,660 


Thunder Bay system 

Cameron Falls — Nipigon river. ... 


115,494,000 


Alexander — Nipigon river 


173,030,400 


Northern Ontario properties 
Nipissing district 

Nipissing — South river 


4,728,040 


Bingham Chute — South river 


3,040,800 


Elliott Chute — South river 


3,989,000 


Sudbury district 

Coniston — Wanapitei river 


16,322,328 


McVittie — Wanapitei river. ... 


12,076,344 


Stinson — Wanapitei river 


17,335,704 


Patricia district 

Ear Falls — English river 


10,679,000 


Abitibi district 

Abitibi Canvon — Abitibi river 


30,950,000 






Total generated 


1,292,700 


t 


2,815,674,823 



*In process of incorporation with the Niagara system. 

fBecause the peak loads on the various generating plants and purchased power sources 
usually occur at different times, the sum of the individual peak loads would not represent the 
sum of the peak loads on the systems. These in the case of each system must relate to the 
maximum load occurring at any one time. Consequently, the column headed "Peak Load" is 
not totalled. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



PURCHASED— ALL SYSTEMS 

POWER PURCHASED 



Power source 



Contract 

amount 

horsepower 

Oct. 31, 1933 



Total 

purchased 

kilowatt-hours 



Canadian Niagara Power Co. — 25 cycle 

Gatineau Power Co. — 25 cycle 

Ottawa Valley Power Co 

Beauharnois Light, Heat and Power Co. . 

McLaren Quebec Power Co 

Canadian Niagara Power Co. — For D.P. & T. 66-cycle system 

Campbellford Water & Light Commission § 

Cedars Rapids Power Co 

M. F. Beach Estate 

Rideau Power Co 

Ottawa & Hull Power & Mfg. Co 

Gatineau Power Co. — 60 cycle 

Orillia Water, Light & Power Commission § 

Manitoulin Pulp Co 

Ontario Power Service Corporation 



Total purchased 



20,000 
260,000 
96,000 
75,000 
20,000 
10,000 

' 7,500 

500 

487 

20,000 

36,000 

"l50 



95,132,300 

,074,498,785 1 

124,024,550 

157,340,000 

28,835,800 

57,855,000 

'29,779,500 

831,600 

2,822,800 

63,660,600 

128,241,500 

—734,530 

99,200 

34,054,060 



1, 796,441, 165t 



Power purchased, contract amount, 1933 
Maximum normal plant capacity, 1933 . . 



545,637 horsepower 
1,292,700 



Total available capacity generated and purchased, 1933 1,838,337 

Total available capacity generated and purchased, 1932 1,760,052 



Difference .(increase) 78,285 

Total energy purchased, 1933 1,796,441,165 kilowatt-hours| 

Total energy generated, 1933 2,815,674,823 kilowatt hours 

Total energy generated and purchased, 1933 4,612,115,988 kilowatt hours! 

Total energy generated and purchased, 1932 4,440,447,470 kilowatt hours}: 

Difference (increase) 171,668,518 kilowatt hours 



Jlncludes secondary power resold to the Gatineau Power Company. 
§Reciprocal arrangement for surplus power. 

CAUTION: The figures for "Maximum Normal Plant Capacity" reflect the capacity of the 
various plants under the most favourable operating conditions which can reasonably be considered 
as normal, taking into consideration turbine capacity as well as generator capacity and also the 
net operating head and available water supply. 

Owing, among other things, to changes in generating equipment due to wear and tear or 
the replacement of parts, also to changes in the limitations governing water levels and effective 
net heads, the maximum normal plant capacity is not a fixed quantity but is one which must be 
revised from time to time. It will be noted that several revisions have been made in the ratings 
shown this year, the capacity of some plants being rated lower and others higher. 

It will be noted that the capacity of the Queenston plant appeared in last year's Report as 
522,000 horsepower and is herein reduced to 500,000 horsepower. The reduction in peak capacity 
is a consequence of operating the plant at a high daily load factor in order to obtain a maximum 
of energy from the water allowable under the Boundary Waters Treaty. At lower daily load 
factors the maximum peak capacity is substantially higher. 

It is particularly important to bear in mind that the column headed "Maximum Normal 
Plant Capacity" cannot be taken as an indication of the dependable capacity of the various plants; 
in some cases it is, but in many cases it is not. As an illustration it may be noted that while 
under favourable circumstances the plants of the Eastern Ontario System, taken collectively, 
might supply a peak demand equal to or even in excess of the sum of their maximum normal 
ratings, the maximum output which could be obtained from them during part of the month 
of October, 1933, was only about 40 per cent of this rating. 

Chief among the factors which govern the maximum dependable capacity of a hydraulic 
power plant and which are not reflected in column headed "Maximum Normal Plant Capacity" 
are abnormal variations in water supply and operating limitations encountered when plants 
are so situated on a given stream as to be affected bv one another. 



10 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

month to month. By June practically all lost ground had been regained, and 
in October the firm load was higher than in the corresponding months of 1932 
or 1931, although still slightly below 1930 which was the record year for all 
time. This steady upward trend of the firm load in Ontario during the latter 
half of 1933 was one of the most encouraging features of the load situation. 
During the months of November and December the normal seasonal increases 
in firm load occurred; thus the gains made during the latter part of the fiscal 
year were retained. 

While the above comments refer to the Commission's load on all systems 
combined, somewhat similar remarks might be made for each system, although 
there are special variations. In the following sub-sections each system is reported 
individually, and load graphs are given showing the load month by month. 

The graphs for the Niagara, Eastern Ontario, and Thunder Bay systems, 
and for the Sudbury, Abitibi and Patricia districts, all show the encouraging 
upward trend during the latter part of the year. The Georgian Bay system 
and the Nipissing district do not share in this gain, but the load continued 
around the same levels as during the previous year. It will be noted that these 
latter systems did not suffer the marked decline of other systems in the earlier 
years of the depression. While not yet showing any upward trend, they were 
later in showing any downward trend, and have little ground to regain. 



Forestry 

The Forestry division's diagnosis of trees on Ontario highways along which 
the Commission's power and telephone lines extend continues to reveal hitherto 
unknown hazards to life, property and service. The reproduction of two photo- 
graphs given herein illustrates only one of the numerous cases which are being 
found on road allowances and on private property adjacent to the Commission's 
lines and to the travelled highways. The Department of Highways, county, 
township and municipal authorities, as well as all property owners, are advised 
of the condition of such trees as these and arrangements made to remove the 
menace. 

Forestry squads have been continuously employed on the Niagara system 
throughout the year, operations being carried on in practically all districts, 
over 1,114 miles of transmission and high-tension telephone lines. Georgian Bay 
system operations were carried on over a period of six months, and embraced 
128 miles of transmission lines in Eugenia, Severn and Wasdells districts. 
Eastern Ontario system operations involved 31 miles of transmission line in the 
St. Lawrence and Central Ontario districts. Some work was done to provide 
adequate clearance for reconstruction required by the Transmission and 
Distribution sections of the Engineering department. 

The work involved in all forestry line-clearance operations, over approxi- 
mately 1,300 miles of Commission-owned power and telephone lines on all 
systems, cost $87,385, including labour, tree wound dressing, cabling and other 
materials as well as travelling expenses and similar Forestry division overhead. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



II 




A MENACE TO LIFE, PROPERTY AND SERVICE 

White pine tree standing alongside the Commission's transmission line on the 
King's Highway No. 11 

LEFT: View of base cavity through which fungus entered, destroying the sap and heartwood 

far up into the trunk 
RIGHT: View of highway, low-tension line and tree 

OPERATING DEPARTMENT— FORESTRY DIVISION 



The work and costs may be classified as below: 





Quantity 


Total 
cost 


Average 
cost 


Underbrushing 


2,239 pole spans 
(or 63 miles) 
12,878 trees 

36,046 trees 


$3,732 
29,104 
54,549 


$1 66 


Tree removals 


2 26 


Line clearance, shaping and corrective pruning. . 


1.51 


Total 


48,924 trees 


$87,385 









It will be noted that this year the costs of underbrushing and tree removal 
have been segregated, whereas in previous years these items were included in 
the total costs and the average cost per tree. The overall cost per tree this year 
shows a slight reduction. 



\2 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

The following is a brief explanation of the work involved in line clearance, 
shaping and corrective pruning: 

(a) The cutting of twigs and branches back to laterals, and the removal 
of all dead wood, to clear lines; 

(b) Corrective trimming by removal of all unsightly diseased stubs, to 
improve the health and appearance of the tree; 

(c) Cabling of structurally weak or splitting crotched trees, and of heavy 

overhanging limbs that could not be removed without impairing the 
symmetry of the tree, for the protection of the Commission's lines and 
of the travelling public. 

(d) Shaping tree by trimming branches beyond area required for line 
clearance, to preserve symmetry of the tree. 

It is estimated that the extensive corrective trimming, shaping, cabling, 
and removal of dead wood required for the first operation on each line costs at 
least fifty per cent more than pruning for line clearance only. On this basis 
the cost of pruning for line clearance alone would amount to about $1.00 per tree. 

Before undertaking pruning operations or tree removals on highways, 
forestry foremen interview both the adjacent property owners and the municipal 
authorities. While this procedure is necessary to secure co-operation and 
harmony, it will be appreciated that it adds to the cost of the operations, and 
such cost is included in the above figures. 

The Forestry division has given the Operating department district patrolmen 
some practical training in the scientific methods of pruning trees for line clearance 
so that they might become qualified to do this work when required. During 
the past year twenty different patrolmen have reported for training while 
forestry operations were in progress in their respective districts. Six completed 
training and were approved. The others were either called for important line 
work or forestry operations were suspended in the district before training was 
completed. They will continue training when forestry operations are re-opened 
in the district. 

During the past year, four municipal Hydro systems have availed themselves 
of the opportunity to employ the Commission's Forestry Division service. They 
report that their commissions and the local property owners are highly pleased 
with the quality of work done and with the efficiency of the foresters in carrying 
on this hazardous class of work without requiring or causing service inter- 
ruptions. This work involved only line clearance pruning, and the removal of 
all dead wood, to clear low-voltage lines. No corrective pruning, extensive 
shaping, or cabling, and only a small percentage of tree removals were required. 
The trees diagnosed as diseased and dangerous were to be removed by the 
unemployed. This type of pruning for local distribution lines is vastly different 
from the clearance required on 10, 000- volt to 60, 000- volt power transmission 
lines. The four municipal operations combined involved pruning 812 trees at 
a total cost of $722, an average cost of 89 cents per tree. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



13 




OPERATING DEPARTMENT-FORESTRY DIVISION 

CROWN AND SIDE PRUNING 
Tree pruned for line clearance and appearance. Only 
crown and side pruning was required for line clear- 
ance, but to avoid destroying the symmetry of this 
tree, the lower branches were trimmed on the line 
and opposite side of tree, increasing the cost but 
preserving appearance 



A complete survey of all trees within the corporate limits has been made 
for several other municipal Hydro systems who later* contemplate the use of 
this service. One of these surveys revealed the fact that of a total of 1,303 trees 
inspected, 101 were diseased and dangerous to life and property. Through co- 
operation with the municipal authorities, these latter trees are being removed 
by the unemployed as a relief measure. 

In co-operation with the Ontario Forestry Branch, the Queenston-Chippawa 
Canal reforestation project was undertaken two years ago to establish a tree- 
lined area on both banks of the canal. This was done primarily to eliminate 
drifting snow and ice, as well as other debris, getting in to the canal, and to 
protect the steep banks from erosion. A rather high mortality among the trees 
resulted from the drouth of the last two seasons. It was, therefore, necessary 
to replace approximately 20,000 trees. The areas immediately surrounding the 
seven bridges are being developed by informal group planting. Approximately 
7,500 conifers of the following species were planted this year: — white cedar, 



14 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Austrian pine, larch, Scotch pine, white spruce, Jack and Muhgo pine. The 
total cost of this year's reforestation and informal development of bridge 
approaches amounted to $727. 

Many letters have been received commending the Commission upon the 
success of its efforts to protect trees along the highways, and to preserve their 
beauty as well as the scenic effect. This is especially gratifying in view of the 
difficulty of preserving the beauty of the trees without sacrificing the clearance 
necessary for satisfactory transmission line operation. 

An expression of gratitude is due the Department of Highways, county, 
township and municipal officials, as well as various property owners, for their 
kind co-operation which has made it possible for this work to be carried on 
harmoniously in all parts of the Province. 

Radio Communication 

The commission's short-wave stations at Toronto, Cameron falls and Ear 
falls have continued in service all year with no important changes in equipment. 
There has not been as much interference from atmospheric and other causes 
as was experienced in 1932, and communication between Toronto and the 
stations mentioned has been maintained on a regular schedule. 



NIAGARA SYSTEM 



Queenston Station 



Generating Stations 



Systematic inspection and maintenance of all apparatus and parts were 
carried out in accordance with the regular schedules, and in this connection 
generator and turbine units were removed from service as noted below. 

Number 1 generator and turbine unit were out of service from June 5 to 
June 23. During this period the governor was dismantled, worn parts were 
replaced and reassembled, the runner and seal ring were inspected, and the 
lignum vitae bearing was reblocked. The generator stator was cleaned and 
varnished and field coils were tested. The Johnson valve was cleaned and the 
valve seats were machined. 

Number 2 unit was out of service from June 26 to July 13. During this 
period the governor was dismantled, worn parts were replaced and reassembled. 
The lignum vitae bearing was reblocked and the runner, draft tubes and seal 
rings were inspected. The generator stator was cleaned and varnished, and the 
Johnson valve controls were cleaned and repaired 

Number 3 unit was out of service from September 1 to September 14, 
during which period repairs were made to the governor controls, the turbine 
bearing was reblocked, and the racks, draft tube, runner and seal rings were 
inspected. The generator windings were cleaned, tested and varnished. 



1934 HYDRO-ELECTRIC POWER COMMISSION 15 

Number 4 unit was out of service from September 18 to October 3. During 
this period the Johnson valve was overhauled, the lignum vitae bearing was 
reblocked and the draft tube, runner and seals were inspected. The governor 
was dismantled and reassembled, worn parts being replaced. 

Number 5 unit was out of service from May 15 to June 3. During this 
period the governor was dismantled and reassembled, worn parts being replaced, 
the lignum vitae bearing was reblocked, the Johnson valve controls were cleaned 
and repaired, and the draft tube was drained and inspected. The generator 
stator and field coils were inspected and cleaned. 

Number 6 unit was out of service from October 10 to October 24. During 
this period the Johnson valve was overhauled and the draft tube, runner and 
seals were inspected. Minor repairs were made to the exciter armature. 

Number 7 unit was out of service from July 14 to July 29, the entire unit 
being dismantled. During this period a large amount of welding was carried 
out on the runner and seal ring. It was found necessary to replace the turbine 
bronze sleeve section on the shaft. The governor was dismantled and reassembled, 
worn parts being replaced. The lignum vitae bearing was reblocked. The 
generator stator and field windings were cleaned and varnished. 

During the above outages of the different units, the low-tension and high- 
tension breakers were inspected and the oil changed. The transformers were 
opened for inspection of all internal connections. 

During the year the governors on units numbers 6, 7 and 9 were equipped 
with load limiting devices, and this work is being continued until all governors 
are so equipped. 

Experiments have been made with the use of stainless steel welding rod for 
the final surface coat on turbine runners during the past few years, and it has 
been found that this metal has several times the life of that previously used. 

A new 32-volt control battery was purchased and installed during the 
latter part of the year, replacing two units previously in service. 

Several hundred trees and shrubs were planted on the gorge banks and 
grounds adjacent to the power house and screen house with a view to beautifying 
the grounds and protecting the gorge banks. 

Ontario Power Station 

The service rendered by the Ontario Power generating station was extremely 
good during the year, there being no failures of major equipment and no diffi- 
culties encountered in its operation. All equipment was regularly inspected 
and repairs and adjustments were made where necessary to maintain the plant 
in efficient condition. All equipment being in good condition, no extensive 
maintenance work was required during the year. 



16 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



HORSEPOW 
1.000.000 



900.000 



800.000 



700.000 



600.000 



500.000 



400.000 



300.000 



200.000 



100.000 



iBiii!isSssa»i!i!i3l8fialniii!isSss8hEifi!i3S^8iuiiiIisSss8. 


1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 j 1 1 1 1 1 1 1 1 


NIAGARA SYSTEM ~T 


PEAK LOADS IN ONTARIO / 


HYDRO-ELECTRIC POWER COMMISSION / 


OF ONTARIO 


I i qoo I , / 


1 i JO O 1 -j 


i i you III /i j r 
\ a. io^? / \ iA I / 




\ \ J \ 1 VI / / \ / 




V*i I J \ U / / \ A / 


\ 1 \ 1 \ / / \ / 


1 \ III t-' / \/ 


/ \ ^ P 


1/ W ^ 1 \ n-oi ! 


V i / til] V i 


I 1 1 t I J 7 i__„T3n___t f . 


± \ ' ] x<& L r l 


\ / i y^ / w 1 

« M / i 1 1 1 11/ u 


/ \ 1 Q9fi V, . J V 


/ \ I II Mi > lll/l 


1QOC / 1 ! X [ i / ^tv / 


9 5 / iNJ / 1 \7 e^ 




ir t t t i:\t-t- 


\ J ' n h J. ' 4 . 4 ,___._! /__ 


^\/ " f .\ui c: J he an nipt toad increase which occurred \ J 


of the Ontario load of the Toronto Power Co. and of \ / 


the Ontario Power Co. In November, 1931, the load of \/ 


the Dominion Power e" 7 ransmisswn Co. was included ~[ t 


of these properties into the Niagara System. 


1 MINI/ 


1Q?^J 


/ 


1Q9? ►/ V A/ - "^ i I 


— — — . . \7D L.C. j 'Xl/ V 


1 Q O 1 / ^ ' 


i y l. i / \ / 
1QOA Mill / N *'"> A / 


1920 U ^ 


^ y\ / ^"^ 1 q 1 fi ' Li 


^s mi7 I I , ■"T 


1 ■ • ■ — I J 1 / r~ 




■p 1915' ^^ , U-H1 j . 


-^ X 101^ >-»** 


1Q1 3 ■ T 


: — - ■ ■ ■ , i i y 1 *- / 

1 Q 1 t i I • I I II I ,- •* ""^ *■ - - - "" "" ~ _ j_ 






lHlIIil«SlsiHilSiiS§lsllSllliilSysll3slIi?i8§IM5lIli?i5sla 



HORSEPOWER 



.000.000 



900.000 



800.000 



700.000 



600.000 



500.000 



400.000 



300.000 



200,000 



100.000 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



17 



HORSEPOWER 



FEB 
MAH 
APR 

JUNE 
Jill Y 
MM) 
SEPT 
OCT 
NOV 
PEC 

JAN 
FEB 

MAR 
APR 

JUNt 
JULY 
AUG 
SEPT 
OCT 

NOV 
OEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUC, 
SEPT 
OCT 
NOV 
OEC 
JAN 
FFB 
MAR 
APR 
MAY 
JUNF 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 

JUNE 
JULY 
AUG 
SEPT 

NOV 


r" 


Total System Load — ^/ 




_, 




Primary Load and Obligations | 

i 




..._ /A /_____,_ 


__!_ t—\-t-—r^/-——U 


H ^t-v n P r 


1.000,000 t- ■ ■ f-- ■ Li -J- --■■[-, -i _ - 

1 i- \ r- , i I J / 


±_ 1 ___ ____ h ]__J 1 S L_ 


_■& i* rt ik __,_____]__ . n __ 


__fc_ r __J_____5 f[V_V_ U\ I 


«.«-__}- V-l- - 'I -W.—UXX-—^-'- 


" M "___^Li_ lL_„, j „ l_-a— -Ll— _Jh- 


ii_ a jl__\____n_ -A— $ 


_ Jj__. -_l_ _H__ I_ Jj y L» H 


F2 L__ ____ t— -J- - M i - 


t *^ / t. f 1 1 r 


800.0M f-r-j \- h Mj 


:::/ _:: * 


1 f u 




______ 

r 


.IQQn IQOI 10*59 1QOO 


iyou iy«_>i iy«_>__. lyoo 








JAN 
HB 
MAR 

MAY 
JUNE 

AIK, 
',EPT 
OCT 
NOV 
DEC 

FEB 

MAR 
APR 

JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 

FEB 

APR 

MAY 

JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FFB 
MAR 
APR 

JUNE 
\LPT 

OCT 

NOV 

DEC 

JAN 
FEB 
MAR 
APR 

JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 



HORSEPOWER 



1,200.000 



1,100,000 



1,000.000 



900,000 



800,000 



700,000 



600,000 



SUPPLEMENTARY DIAGRAM— NIAGARA SYSTEM PEAK LOADS 

Notes 

TOTAL SYSTEM LOAD includes power exported to Quebec and the United States 
as well as the Ontario load shown on the opposite page 

PRIMARY LOAD AND OBLIGATIONS as the term implies, includes both the 
primary load and the contractual obligations for primary power to Ontario 
Companies supplied directly by the Commission in excess of power actually taken 
by them 



The scaling of the cliff, and the construction of a dry wall to protect the 
buildings from falling rock, which was reported under way in the last Annual 
Report, was completed during the latter part of 1932. Repairs were made to 
the outer concrete walls of the power house. 

All machine shop equipment is being moved to a permanent location in 
the north end of the main generating station, in a space formerly occupied by 
a 16-foot boring mill which has been moved to Queenston. The relocation of 
this equipment will permit the removal of temporary buildings at the north 
end of the power house which were originally erected for construction purposes. 



18 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Toronto Power Station 

No difficulties were encountered in the operation of this plant during the 
year, although two generators failed in service during a lightning storm on 
July 19, and required minor repairs. Systematic inspection and maintenance 
of all apparatus was carried out in accordance with the regular schedules; the 
larger maintenance items are as noted below. 

On number 1 unit the upper turbine rods were packed and the lower turbine 
bearing was changed. 

The generator on number 3 unit failed in service on July 19 during a lightning 
storm and it was found necessary to replace three coils in the armature. The 
stator was given a thorough cleaning, and all coils were varnished. 

On number 4 unit the field was removed and the stator coils cleaned and 
varnished. During this period the oil and water service pipes to both generator 
bearings were re-arranged. The governor was dismantled, worn parts were 
replaced and the governor was reassembled. The turbine and guide bearings 
were also refitted. 

On number 5 unit the upper turbine bearing was changed and the lower 
turbine bearing was inspected. The guide bearings on decks number 3, 4 and 5 
were inspected and the oil grooves recut. Steel gear guards were installed under 
the governor, and the wheel-gates were adjusted to provide for tighter closing. 

On number 6 unit the field was removed and the generator coils were cleaned 
and varnished. The guide bearings on decks number 2. 3 and 4 were inspected 
and oil grooves recut, and the guide bearing on deck number 5 was replaced. 
The top and bottom generator bearings were changed, and steel gear guards 
were placed under the governor. 

The armature of number 7 unit failed in service on July 19 during a lightning 
storm, and it was necessary to remove the field and replace five coils in the 
armature. The stator was thoroughly cleaned and the coils re varnished. The 
top generator bearing and the guide bearings on deck number 5 were changed. 

During the severe wind and lightning storm on June 7 a 6,000 kv-a. trans- 
former at the Toronto Power transformer station failed in service. This unit 
has not yet been repaired. 

The usual painting and general maintenance work was carried out in 
accordance with the regular schedules. 



Ghats Falls Station — Ottawa River 

The year 1932-3 was the first complete year's operation with eight units 
in service. The performance of all equipment was highly satisfactory, requiring 
no major maintenance or repair work. All inspection and routine maintenance 
work has been carried out in accordance with a regular schedule. A complete 
check of all relay and metering equipment was made. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



KILOWATT-HOURS 



400.000.000 




SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 

APR 

JUNE 

AUC 
S£PT 
OCT 
NOV 
OEC 

FEB 

MAR 
APR 

JULY 

SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
S£PT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 




[ 1 M 1 II 1 II i 1 1 II 1 I II II 1 1 It 1 1 1 1 1 ] 






NIAGARA SYSTEM 






. TOTAL KILOWATT-HOUR LOAD _ 






IN ONTARIO 
















HYDROELECTRIC POWER COMMISSION 




- 


! 1 1 1 1 1 - 




1 oon 


Mill 

1QOO 




i y ju 


ii?oo 


300.000.000 


u 


"" - i~ J" 




-1 Q *3 9 - """■*_ 




- 


I lyo^ - _ 

1 QQ1 - " 






I yo i _ _ __ 




_ 


~ " _ — = ~ ~ lyZy : 






- * 






- n . ~ - 1 " 






- "" - _"- - 






-__ -_ 






- - 1QOQ - 


200.000.000 




__ - - _ 13/P 


- 


1 _ _- m 

- 1 Q07 - 




- 


- i, y L. / 

\c\oc. Ill I I r , - — 




_ _-- 


1 "f-O III 




- IQ*?^ 


NOTE: The abrupt load tnrrease which occurred 




i yzD 


of the Ontario load of the Toronto Power Co. and of 1Q?A 






the Ontario Power Co. In November, 1931, the load of 






the Dominion Power & Transmission Co. was included 






of these properties into the Niagara System. 






U 


100.000,000 




I . ±:.=4=: 




~ - - 1 QOQ - 






iy^o 










- - 


-_- n 

.1QOO . -~ 










-lyzu 


- ■ ■ \zf/L\ n 

1Q1Q 






iy i y 






m 















IAN 

IEB 

APR 
MAI 

JUNE 


SEPT 

NOV 

JAN 
FtB 

APR 

JUNE 

AUG 
SEPT 

OCT 

DEC 

FEB 

MAR 

JUNE 
JULY 

bEPT 
OCT 
NOV 

DEC 

EEB 

APR 

JUNE 

AUG 

OCT 

DEC 
JAN 
EEB 

APR 

JUNE 
JULT 
AUG 

OCT 

DEL 



KILOWATT-HOURS 



400.000.000 



300.000,000 



200.000,000 



100.000.000 



The Ottawa river flow reached a maximum of 150,000 c.f.s. during the 
spring flood and receded to a minimum of 12,000 c.f.s. in October, the extremely 
low flow resulting from the small precipitation during the summer. Throughout 
this wide variation of flow no difficulty was experienced in maintaining the water 
levels within the prescribed limits. 



The responsibility for maintaining system frequency and time service was 
transferred to this station from the Niagara Falls plants during the year. For 
this purpose a type "B" Telechron clock was installed in the control room, 
which, in conjunction with a graphic time-error meter installed at the load 



20 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

supervisor's office at Niagara Falls, enables the operators to maintain time 
service to the districts supplied from Toronto, York, Cooksville and Hamilton 
transformer stations within the limits of plus or minus five seconds from standard 
time. Similar time service is given to other parts of the Niagara high-tension 
system through frequency control at Niagara Falls. 

For the purpose of placing cars, moving heavy material and handling tail- 
race stop-logs, a large Browning crane was purchased. 

During the early part of the past fiscal year the remaining construction 
details were completed. A complete inventory has been made of all construction 
material, stores, spare parts, etc., remaining on hand after the completion of 
construction, and this material is now being offered for sale. 

Decew Falls Generating Station 

This plant was in continuous operation throughout the year; no difficulties 
were encountered in its operation, and no failures of equipment occurred. No 
extensive maintenance work was carried out during the year, but regular 
inspection and repairs were made in accordance with the established schedule, 
and the plant was kept in satisfactory operating condition. 

The water-wheel governors of number 5 and number 7 units were rebuilt 
and a new main control valve was built for number 1 water-wheel. The exterior 
trim of the generating station building and transformer house was painted. 

Dominion Power Steam Station — Hamilton 

The 60-cycle steam plant at Hamilton was operated during the year as a 
standby for electric service and for the generation of steam for commercial 
purposes. While it was not necessary to operate the steam turbo-generator for 
power purposes during the year, this unit was operated from time to time as 
a synchronous condenser for voltage regulation on the system. Experiments 
were carried out in the burning of coke breeze, along with the regular slack 
coal. These were successful and fuel costs at this station have been reduced. 



Transmission 

The 220,000-volt lines between Toronto and the Ottawa river (Chats Falls), 
and from this point to the Ontario-Quebec boundary line connecting with the 
Beauharnois development, gave very satisfactory service and no difficulties were 
encountered in the operation or maintenance of these lines. 

There were two total interruptions of all three circuits, caused by lightning, 
resulting in disturbances to service in the Toronto area. There were fourteen 
single-circuit outages on this system caused by lightning; these latter outages, 
however, did not affect service. None of the above disturbances caused damage 
to lines or equipment, and the immediate return of the equipment to service 
was possible. 



1934 HYDRO-ELECTRIC POWER COMMISSION 21 

On July 1, the 220, 000- volt circuit from the Masson station of the MacLaren- 
Quebec Power Company was connected to the Beauharnois-Chats Falls line and 
placed in service. 

The towers on the three circuits between Leaside station and Hastings 
interswitching station were Inspected, all bolts tightened and palnuts installed, 
in order to prevent the loosening of the tower bolts by vibration. Along with 
this work the conductors on the original circuit were inspected. Underbrushing 
was carried out on approximately four thousand acres from a point north of 
Oshawa to the Ottawa river. 

There were no complete interruptions on the 110, 000- volt transmission 
system during the year. There were, however, interruptions on the three 
individual groups of this system. 

On March 19 a sleet storm of moderate severity caused interruptions to 
all customers west of Dundas. 

On June 7 a storm of extreme seventy, accompanied by high winds, lightning 
and rain, caused extensive damage in many districts between London, Toronto 
and Niagara Falls. At this time six towers collapsed on the circuits between 
Dundas and Toronto, and six towers on the right-of-way near Stoney Creek. 
Damage also occurred to low-tension lines in the Dundas, London, St. Marys, 
and Niagara Falls districts. 

In addition to the usual patrol, minor maintenance and repair work after 
storms, the following maintenance work was carried out on the 110, 000- volt 
lines. Some 705 McGuigan type towers, from a point between Dundas and 
Guelph, to between London and St. Marys, were cleaned and painted, and the 
majority of the towers on the Toronto circuits from Niagara Falls were inspected 
and the bolts were tightened. Palnuts were installed on the towers between 
Allenburg junction and St. Thomas, and extensions erected on transposition 
towers to improve loop clearance. The Archibolt-Brady 60,000-volt towers 
between Niagara station and the river crossing were cleaned and painted, also 
several 46,000-volt towers, including the towers at the canal crossing in Welland. 

m 

Extensive underbrushing was done on the older tower lines between Niagara 
Falls and Toronto, and westerly as far as St. Thomas. The 110, 000- volt circuits 
were re-arranged at our Strachan and York stations and at Saltfleet and Halton 
junctions. High-tension insulators were meggered between Kitchener and 
London and on other circuits in the vicinity of London. A short section of line 
was pladed in service between the Holland Road junction and the Ontario 
Paper Company (Steam) transformer station. 

A new transformer station of 67,500-kv-a. capacity, along with three 
30,000-kw. steam generators, was placed in service at the Ontario Paper 
Company on January 29. 

The Commission's private telephone service was extended during the year 
to the following stations on the Dominion Power division: DeCew Falls, 
Hamilton steam plant, Beamsville, Grimsby and Ancaster distributing stations, 



22 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Bartonville switching station, Lincoln Electric Company, St. Catharines, and 
the Hamilton field office, thus making telephone communication available 
between these points and all other points on the Commission's telephone system. 

On the Dominion Power lines there was no total interruption to service 
during the year, or any reduction in load due to failure of generation. On the 
44,000-volt lines there were two interruptions totalling ten minutes. The violent 
storm of June 7 damaged sections of transmission circuits and caused interruptions 
to customers in the Brantford, Grimsby, Oakville and Welland areas. 

The 44,000-volt pin-type insulators were visually inspected during the year 
and all defective units replaced. A portion of the 24,000-volt insulators were 
also visually inspected and the defective units changed. Extensive maintenance 
work was carried out on the circuits serving Brantford, and these sections are 
now in good operating condition. Considerable maintenance work was carried 
out on the circuit between Bartonville switching station and Ancaster distribution 
station. 

Transformation 

At Bridgman-Davenport station hand-operated tap changers were installed 
on six 5,000-kv-a. high-tension transformers. At Wiltshire station three trans- 
formers were sent to the manufacturer for the installation of hand-operated tap 
changers, and this same equipment was also installed on thirty-four units at 
the station. 

The core bracing was inspected and tightened on fifty-three 5,000-kv-a. 
transformers during the year. 

At Dundas station one 5,000-kv-a. transformer failed in service during the 
storm of June 7. There was also a failure of one 1,250-kv-a. unit at St. Thomas. 
Both of these units have been rebuilt by the maintenance staff. 

A new guided-wave radio transmitter and receiver was installed at Brant 
station, and the equipment in Strachan Avenue station was moved to Stratford. 

Two complete inspections and overhaul of all outdoor breakers were carried 
out during the year, along with one complete inspection of the 110, 000- volt 
indoor circuit breakers. In addition to this the regular schedule of inspection 
and maintenance was carried out at all high-tension stations. 

Distribution 

There were no new low-tension transformer stations put in service during 
the year, and no changes made in transformer capacity to any of the existing 
stations. There were twelve failures of low- tension transformers, ten of which 
were rebuilt in the field, and two units were scrapped. A new bank of trans- 
formers was installed at Toronto station, replacing three units of similar capacity 
which failed in service. 

In the Brant district the railway and wire crossings were made standard. 
Extensive general overhauling of low-tension lines was carried out in the Preston, 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



23 



COKC OVEN 



BEACH 



— o 



Firestone 

OH, 

NATIONAL CAR 

0^1 



CAN CRUSHED STONE, DUNDAS. STEEL CO. < 



t 




gf5f>Wfl| 
STEAM PLANT 



Van. west cc 



^M' ^". \ 



C0CK5HUTT ' 



TMl — L 



BRANT FORD 



□ 



LEGEND 






'.rrLCET RPO (PART) 
* \ RCA M 5 Wi LE PRO 



■ HOMER 

1 1 - ! — ► GRANTHAM R.Pl 

«/l>-fS WHEEL 

-i—b 



BARTONVILLE 



id. OCOIY. I 5«.«o I 

-H H |*oor«»CT| 

□■ycwrK «"«* [J 
1— ► SALTFLEET R.PD 



GRANTHAM RPD.fPART) 

CAN. NIAGARA 

±^m [55] 



•SALTTLCET R.PD(PAPT) 



5T. CATHARINES 



HORSEPOWER 



SCOTTISH rCRTILIZER 



HORSEPOWER AT RATED POWER FACTOR) 

IV I SWITCHING STATION 

\T)TYl FREQUENCY CHANCER 

l^Jrj /7/V TRANSFORMER STATION) 

□ DISTRIBUTING STATION 

O MUNICIPAL 0R CUSTOMERS STATIONS 

STATIONS S LINES IN SERVICE 

STATIONS <f £//V£\S /i<pr commission's property 

If. Pa RURAL POWER DISTRICT 



~o 



NIAGARA SYSTEM 
DOMINION POWER AND TRANSMISSION 



DIAGRAM OF STATIONS 

AS »T OCTOBER II. IM3 



YDRO-ELECTRIC PO*ER COMMISSION 



Stratford, Woodstock, Brant and Kent stations. New air-break switches and 
switching structures were erected at Britannia junction and at Beach ville 
substation. 



In order to obtain a longer life from wood poles, approximately 23,000 
poles were uncovered at the ground line, the decayed wood removed, and the 
poles given a spray treatment of creosote. 

There were no new 26, 000- volt or 13, 000- volt lines placed in service during 
the year. 

In the Dominion Power division, two 500-kv-a. transformers failed in service 
during the year, one at St. Catharines distributing station, and one at the 
Beatty-Welland distributing station. Both of these units were rewound and 
restored to service. The transformer failure at the Beatty-Welland substation 
was caused by lightning, the failure resulting in a fire which destroyed the 
station. Equipment was removed to a temporary substation and service was 
restored. Transformer stations at Thorold and Humberstone were dismantled, 
some of the equipment being salvaged and the balance disposed of. Service to 
the Welland Ship canal at lock No. 8, Humberstone guard gate, and lock No. 2 
Port Weller, and to the National Fireproof Company, was discontinued during 
the year. 



24 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA SYSTEM— LOADS OF MUNICIPALITIES, 1931-1932-1933 



Municipality 



Peak load in horsepower 



Oct. 1931 Oct. 1932 Oct. 1933 



Change in load 
1932-1933 



Decrease Increase 



Acton 

Agincourt 

Ailsa Craig 

Alvinston 

Amherstburg 

Ancaster Township. 

Arkona 

Aurora 

Aylmer 

Ayr 



Baden 

Beachville 

Belle River 

Blenheim 

Blyth 

Bolton 

Bothwell 

Brampton 

Brantford 

Brantford Township. 

Bridgeport 

Brigden 

Brussels 

Burford 

Burgessville 



Caledonia. . . . 
Campbellville 

Cayuga 

Chatham . . . . 
Chippawa. . . . 

Clifford 

Clinton 

Comber 

Cottam 

Courtright . . . 



Dashwood . 
Delaware . . 
Dorchester. 
Drayton . . 
Dresden . . . 
Drumbo. . . 
Dublin. . . . 
Dundas. . . . 
Dunnville. . 
Dutton. . . . 



East Windsor 

Elmira 

Elora 

Embro 

Erieau 

Erie Beach 

Essex 

Etobicoke Township 
Exeter 



681.7 


149.0 


147.9 


94.2 


714.5 


277.5 


55.3 


968.3 


490.6 


207.6 


281.2 


329.7 


146.8 


379.3 


93.5 


131.7 


104.5 


2,345.9 


9,129.9 


530.8 


130.2 


S3. 3 


134.4 


143.6 


55.2 


378.4 


27.3 


96 2 


4,167.0 


261.4 


63.0 


462.4 


125.7 


69.3 


40.7 


69.3 


37.6 


81.7 


96.8 


319.0 


64.2 


48.6 


1,280.1 


786.0 


236.8 


2,761.4 


777.5 


411.5 


98.5 


61.6 


11.1 


372.1 


3,159.5 


404.8 



787.6 


155.2 


81.5 


87.9 


661.6 


284.5 


52.6 


986.6 


513.4 


161.1 


237.9 


386.6 


124.6 


369.9 


101.4 


118.8 


105.2 


2,168.2 


1,637.9 


505.1 


108.4 


88.4 


132.1 


136.4 


57.1 


320.7 


26.2 


119 9 


4,285.0 


218.0 


58.1 


408.8 


158.1 


62.7 


39.4 


65.9 


41.5 


67.0 


99.4 


286.1 


67.7 


34.2 


1,138 


797.1 


237.4 


2,450.4 


646.1 


384.7 


83.8 


70.7 


8.0 


336.4 


3,361.9 


424.9 



832.6 

116.6 

88.6 

82.8 


38.6 

"5.r 

45.0 
0.7 

7.2 


45.0 

7*.i" 


616.6 

283.8 




45.4 




1,030.1 


43.5 


469.1 

157.5 

241.7 

387.4 


44.3 
3.6 


3.8 
0.8 


119.3 


5.3 
16.0 
14.0 




353.9 




87.4 




137.7 


18.9 


104.4 


0.8 
93.0 




2,075.2 




12,728.7 


1,090.8 


605.6 




100.5 


85.5 


22.9 




89.1 


0.7 


108.8 


23.3 

20.9 

3.0 




115.5 




54.1 




327.7 


7.0 


24.2 


2.0 

7.3 
26.9 

2.7 




112.6 




4,258.1 




215.3 




61.5 


3.4 


374.5 


34.3 




164.0 


5.9 


58.0 


4.7 

1.0 

25.9 
6.4 

"l2'7 
6 1 
14 




38.4 




40.0 




35.1 




95.7 
86.7 


28.7 


280.0 




66.3 




42.9 


8.7 


1,276.1 




138.1 


907.7 




110.6 


211.9 


25.5 

172.7 
88.5 
93.3 




2,277.4 




557.6 




291.4 




104.5 


20.7 


72.6 




1.9 


6.4 


16 




361.9 


25.5 


3,621.4 
382.0 


42.9 


259.5 







1934 



HYDRO-ELECTRIC POWER COMMISSION 



25 



NIAGARA SYSTEM— LOADS OF MUNICIPALITIES, 1931-1932-1933— Continued 



Municipality 



Peak load in horsepower 



Oct. 1931 Oct. 1932 Oct. 1933 



Change in load 
1932-1933 



Decrease Increase 



Fergus 

Fonthill 

Forest 

Gait 

Georgetown 

Glencoe 

Goderich 

Granton 

Guelph 

Hagersville 

Hamilton 

Harriston 

Harrow 

Hensall 

Hespeler 

Highgate 

Humberstone 

Ingersoll 

Jarvis 

Kingsville 

Kitchener 

Lambeth 

La Salle 

Leamington . + 

Listowel 

London 

London Township V.A 

Long Branch 

Lucan 

Lynden 

Markham 

Merlin 

Merritton 

Milton 

Milverton 

Mimico 

Mimico Asylum 

Mitchell 

Moorefield 

Mount Brydges 

Newbury 

New Hamburg 

Newmarket 

New Toronto 

Niagara Falls 

Niagara-on-the-Lake 

Norwich 

Oil Springs 

Ontario Agricultural College. 
Ontario Central Reformatory 
Otterville 



686.3 


163 6 


305.6 


6,301.6 


889.0 


173.2 


983.4 


93.4 


7,794.9 


943.7 


86,641.1 


311.6 


368.6 


165.5 


1,831.4 


59.9 


384.7 


1,915.9 


179.9 


446.4 


15,834.7 


107.2 


241.3 


1,065.9 


865.3 


27,908.8 


311.2 


754.1 


174.1 


83.1 


238.6 


91.8 


2,281 5 


705.3 


344.5 


2,103 1 


65.0 


500 


48.2 


89.0 


41.8 


492.3 


1,340.5 


5,194.4 


9,351.2 


536.2 


331.7 


156.9 


401.6 


282.8 


83.6 



652.5 


138.5 


332.1 


6,071.1 


902.7 


170.8 


970.5 


90.4 


7,710.5 


1,046.9 


76,409.6 


289.2 


332.1 


150.4 


1,864.9 


61.6 


324.4 


1,870 


178.7 


420.9 


14,874.6 


99.6 


211.5 


1,112.6 


906.1 


29,437.4 


371.4 


736.0 


134.0 


74.5 


249.3 


94.7 


2,737.3 


597.1 


311.4 


2,211.8 


65.0 


422.2 


58.2 


92.7 


43.4 


470.2 


1,380.7 


4,766.7 


8,774.0 


548.8 


335.1 


172.7 


427.6 


249.3 


77.7 



705.0 


133.2 


320.6 


5,858 7 


978.3 


163.7 


991.9 


96.5 


7,812.3 


418.2 


83,832.3 


247.2 


332.7 


121.6 


1,879.7 


69.0 


386.7 


1,969 


150.1 


431.6 


15,000.6 


94.9 


199.0 


1,327.0 


808.3 


30,201.2 


358.5 


733.9 


136.0 


66.3 


211.8 


66. 7* 


2,765.1 


804.4 


295.6 


2,218.5 


100.0 


433.8 


45.5 


79.6 


40 6 


399.1 


1,285 5 


4,790 8 


9,135.6 


546.1 


308.3 


159.3 


469.1 


243.9 


84.3 



5.3 
11.5 

212.4 

" 7 '. i 



628.7 
42'0 
28'8 



28.6 



4.7 
12.5 



97 



12.9 
2.1 



8.2 

37.5 
28.0 



15.8 



12.7 
13.1 

2.8 
71.1 
95.2 



2.7 
26.8 

13.4 



5.4 



52.5 



75.6 



21.4 

6.1 

101.8 



7,422.7 

"6!6 



14.8 

7.4 

62.3 

99.0 



10.7 
126.0 



214.4 
763^8 



2.0 



27.8 
207.3 



6.7 
35.0 
11.6 



24.1 
361.6 



41.5 



6.6 



26 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA SYSTEM— LOADS OF MUNICIPALITIES, 1931-1932-1933— Continued 



Municipality 



Peak load in horsepower 



Oct. 1931 Oct. 1932 Oct. 1933 



Change in load 
1932-1933 



Decrease Increase 



Palmerston 

Paris 

Parkhill 

Petrolia 

Plattsville 

Point Edward 

Port Colborne 

Port Credit 

Port Dalhousie. . . . 

Port Dover 

Port Rowan 

Port Stanley 

Preston 

Princeton 

Queenston 

Richmond Hill . . . . 

Ridgetown 

Riverside 

Rockwood 

Rodney 

St. Catharines 

St. Clair Beach 

St. George 

St. Jacobs 

St. Marys 

St. Thomas 

Sandwich 

Sarnia 

Scarboro Township. 

Seaforth 

Simcoe 

Springfield 

Stamford Township 

Stouffville 

Stratford 

Strathroy 

Sutton 

Tavistock 

Tecumseh 

Thamesford 

Thamesville 

Thedford 

Thorndale 

Thorold 

Tilbury 

Tillsonburg 

Toronto 

Toronto Township. 

Walkerville 

Wallaceburg 

Wardsville 

Waterdown 

Water ford 

Waterloo 



518.9 

1,242.0 

140.7 

731.4 

60.8 

267.4 

1,608.6 

537.5 

457.1 

315.2 

74.2 

220.9 

3,128.6 

101.3 

87.1 

317.3 
416.9 
1,212.7 
104.5 
145.6 

8,449.7 
97.6 
92.5 

140.2 
1,521.9 
5,643.4 
3,459.3 
6,801.6 
3,034.8 

510.9 

1,491.1 

52.9 

1,831.1 

194.7 
7,790.6 
1,000.0 

150.4 

523.6 

443.8 

154.1 

178.3 

60.8 

46.1 

1,941.7 

321.7 

884.7 

289,262.7 

1,668.1 

6,348.5 

1,059 

38.0 

231.9 

380.0 

2.946.2 



458.5 

1,178.4 

131.3 

761.7 

53.3 

689.0 

1,407.5 

549.3 

439.7 

315.6 

73.0 

228.5 

2,560.3 

103.2 

83.5 

297.0 
439.7 
1,200.6 
104.5 
145.7 

7,872.8 

90.7 

147.4 

152.8 

1,501.8 

5,761.4 

2,996.4 

7,360.6 

3,124.6 

465.3 

1,546.1 

65.6 

1,859.8 

204.1 

7,180.2 

910.2 

152.7 

496.0 
302.2 
158.8 
171 

57 

40 

1,956 

366 

891 




6 
6 
4 
6 


280,795.0 
1,868.0 

5,454.7 

1,252.0 

35.4 

191.7 

406.8 

2,660.8 



437.5 

1,197.2 

124.2 

685.8 

60.2 

636.7 

1,420.9 

611.2 

503.7 

296.5 

67.1 

261.5 

2,461.1 

98.8 



80.7 

293.1 

446.4 

1,104.9 

89.8 

131.1 

7,854.2 

72.6 

129.3 

151.4 

1,225.7 

6,179.6 

2,956.2 

7,581.1 

2,981.5 

408.8 

1,613.9 

59.0 

1,819.0 

167.9 

6,530.9 

946.4 

153.5 

424.6 

294.7 

159.5 

163.5 

127.0 

36.4 

1,914.6 

398.1 

900.1 

269,144.8 

1,793.7 

5,336.4 

1,888.7 

34.3 

201.0 

399.4 

2,668.9 



21.0 



7.1 
75.9 



52.3 



19.1 
5.9 



99.2 
4.4 

2.8 

3.9 



95.7 
14.7 
14.6 

18.6 

18.1 

18.1 

1.4 

276.1 



40.2 



143.1 
56.5 



6.6 

40.8 

36.2 

649.3 



71.4 

7.5 



7.5 



4.2 
41.8 



11,650.2 
74.3 

1183 



1.1 

7.4 



18 


8 




6 


9 


13 


4 


61 


9 


64 






33.0 



6.7 



418.2 
220*5 



67.8 



36.2 
0.8 



0.7 
69^4 



31.5 
9.1 



636.7 
"9.3 

"s.'i 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



27 



NIAGARA SYSTEM— LOADS OF MUNICIPALITIES, 1931-1932-1933— Concluded 



Municipality 



Peak load in horsepower 



Oct. 1931 Oct. 1932 Oct. 1933 



Change in load 
1932-1933 



Decrease Increase 



Watford 

Welland 

Wellesley 

West Lome 

Weston 

Wheatley 

Windsor 

Woodbridge 

Woodstock 

Wyoming 

York, East Township. . 
York, North Township 

Zurich 



200 


4 


3,967 


8 


142 


7 


97 


8 


2,619 


2 


155 


7 


25,431 


8 


293 


5 


4,781 


5 


60 


3 


5,138 





2,757 


4 


85 


9 



186 


3 


3,576 


4 


97 


7 


105 


9 


2,453 


1 


143 


1 


23,029 


9 


247 


9 


4,785 


5 


64 


6 


5,504 





2,829 


7 


76 


4 



185 





3,918 


2 


94 


7 


98 


6 


2,790.8 


123 


7 


0,550 


3 


261 


4 


4,950 


4 


75 


2 


5,330 


7 


2,890 





64 


8 



1.3 



3 

7 




3 


19 
2,479 


4 
6 






173 


3 



11.6 



341.8 



337.7 



13.5 

164.9 

10.6 



60.3 



NIAGARA SYSTEM— RURAL POWER DISTRICT LOADS, 1931-1932-1933 



Municipality 


Peak load in horsepower 


Change in load 
1932-1933 




Oct. 1931 


Oct. 1932 


Oct. 1933 


Decrease 


Increase 


Acton. . .' 


10.0 

5.6 

3.2 

518.8 

304.8 

32.0 

293.0 
1,072.2 
269.9 
153.5 
840.7 
102.7 
127.3 
565.2 
35.7 
145.3 

260.5 
434.0 
109.9 
124.6 

297.2 
335.9 

28.5 
64.6 

552.3 
29.0 

115.7 


10.0 

5.6 

3.2 

533.7 

294.4 

42.5 

398.6 
1,061.1 
254.9 
1 43 . 6 
897.2 
115.6 
133.3 
464.9 
38.0 
155.9 

322.0 
441.3 
102.2 
125.2 

265.3 

329.4 
34.6 
79.2 

578.3 
42.0 

122.8 


10.0 

5.6 

3.2 

496.7 

291.1 

42.5 

367.1 
1,030.7 
220.0 
118.5 
926.4 

89.0 
130.0 
434.4 

31.5 
170.5 

300.5 

473.5 

99.2 

121.7 

299.5 

269.2 
42.2 
59.0 

582.6 
42.0 

126.0 






Ailsa Craig 






Alvinston 






Amherstburg 


37.0 
3.3 




Aylmer 




Ayr 




Baden 


31.5 
30.4 
34.9 
25.1 




Beamsville 




Belle River. . . . 




Blenheim 




Bond Lake. . 


29.2 


Bothwell 


26.6 
3.3 

30.5 
6.5 




Brampton 




Brant 




Brigden 




Burford 


14.6 


Caledonia. . 


21.5 




Chatham 


32.2 


Chippawa 


3.0 
3.5 




Clinton 




Delaware 


34.2 


Dorchester 


60.2 




Dresden .... 


7.6 


Drumbo. . . . 


20.2 




Dundas. . . . 


4.3 


Dunnville. 






Dutton . 




3.2 









28 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA SYSTEM— RURAL POWER DISTRICT LOADS, 1931-1932-1933— Continued 



Municipality 



Peak load in horsepower 



Oct. 1931 Oct. 1932 Oct. 1933 



Change in load 
1932-1933 



Decrease Increase 



Elmira 

Elora 

Essex 

Exeter 

Forest 

Gait 

Georgetown 

Goderich 

Grantham Township 
Guelph 

Haldimand 

Harriston 

Harrow 

Ingersoll 

Jordan 

Keswick 

Kingsville 

Listowel 

London 

Lucan 

Lynden 

Markham 

Merlin 

Milton 

Milverton 

Mitchell 

Newmarket 

Niagara 

Norwich 

Oil Springs 

Palmerston 

Petrolia 

Preston 

Ridgetown 

St. Jacobs 

St. Marys 

St. Thomas 

Saltfleet 

Sandwich 

Sarnia 

Scarboro Township. 

Seaforth 

Simcoe 

Stamford 

Stratford 

Strathroy 

Streetsville 



72.7 


139.8 


213.9 


217.6 


28.0 


179.6 


132.4 


71.5 


643.2 


392.1 


193.2 


22.1 


399.4 


370.6 


200.0 


291 1 


526.6 


113.9 


1,451.8 


65.3 


160.0 


387.7 


157.5 


124.8 


74.5 


190.4 


290.3 


598.9 


207.7 


45.5 


31.5 


25.3 


848.1 


284.2 


241.9 


243.6 


465.0 


1,114.6 


1,008.3 


491.1 


315.0 


46.3 


175.0 


193.0 


176.1 


96.6 


376.2 



79.6 


105.7 


201.0 


245.5 


28.0 


197.9 


134.8 


84.0 


527.1 


415.5 


240.0 


23.9 


345.1 


329.8 


320.0 


381.6 


545.8 


131.9 


1,509.0 


64.6 


177.2 


453.0 


175.2 


128.2 


69 5 


187.8 


255.7 


434.5 


202.3 


44.9 


37.5 


25.3 


848.2 


260.8 


218.5 


210.4 


469.3 


1,029.9 


1,001.9 


466.4 


296.6 


47.8 


231.0 


185.1 


164.9 


95.0 


324.3 



70.2 


98.2 


189 6 


235.3 


28.0 


181.3 


124.9 


84.2 


611.1 


411.5 


164.0 


20.0 


323.6 


337.8 


282.0 


395.8 


453.5 


132.7 


1,523.7 


60.2 


166.5 


423.8 


177.5 


140.0 


65.5 


172.2 


225.3 


395.9 


241.3 


45.5 


48.0 


25.3 


854.7 


227.9 


268.8 


183.8 


483.2 


966.1 


908.0 


485.3 


358.4 


53.2 


205.4 


156.5 


104 6 


93.2 


251.1 



9.4 

7.5 
11.4 
10.2 



16.6 
9.9 



4.0 

76.0 

3.9 

21.5 



38.0 



92.3 



4.4 
10.7 

29.2 



4.0 

15.6 

30.4 
38.6 



32.9 



26.6 



63.8 
93.9 



25.6 
28.6 
60.3 
1.8 
73.2 



934 



HYDRO-ELECTRIC POWER COMMISSION 



29 



NIAGARA SYSTEM— RURAL POWER DISTRICT LOADS, 1931-1932-1933— Concluded 



Municipality 


Peak load in horsepower 


Change in load 
1932-1933 




Oct. 1931 


Oct. 1932 


Oct. 1933 


Decrease 


Increase 


Tavistock. 


165.7 

105.9 

78.1 

321.3 

180.5 

128.7 

84.5 

830.5 

129.2 

17.6 

1,115.3 

561.9 

480.6 


194.4 
100.9 
119.4 
302.4 

179.8 
150.8 

70.7 
906.5 
158.2 

16.4 

1,161.8 

550.0 

487.4 


153.6 
108.6 
134.6 
314.4 

173.1 

144.3 

82.8 

676.2 

174.9 

22.0 

1,079.1 

537.9 

483.3 


40.8 




Thamesville 


7.7 


Tilbury 

Tillsonburg 




15.2 




12.0 


Wallaceburg 


6.7 
6.5 




Walsingham 




Walton . 


12.1 


Waterdown 


230.3 




Waterford 


16.7 


Watford . . 




5.6 


Welland 


82.7 

12.1 

4.1 




Woodbridge 




Woodstock 









GEORGIAN BAY SYSTEM 

The Georgian Bay system peak and average loads both show a decrease 
of approximately three per cent compared with last year and this is almost 
entirely due to the reduced demands in the Midland areas, plus the loss of 
considerable load owing to two large stone crushing plants closing down for the 
greater part of the year. 






Storage water reserves on the system were considerably below normal 
toward the latter part of the year, due to the exceedingly hot summer combined 
with a long period of low precipitation, and stream flows were reduced to such 
an extent that from July until the end of the year it was necessary to supply a 
large amount of power from the Niagara system, through the Hanover frequency 
changer set, in order to conserve water for plant operation over the winter 
period. Assistance was given to the Orillia Water, Light and Power Commission 
during this period, as Orillia's plant at Swift rapids was unable to carry its 
load due to reduced flows in the Severn river. 



A new 22, 000- volt transmission line was built from a point on the old line 
about two miles west of Shelburne, south, to intersect the old line running west 
to Grand Valley. From the point of intersection, east to the former Grand Valley 
junction, the old line was restrung with larger conductor and a new line built 
from this point to Orangeville. The new line was required as the old line was 
of insufficient capacity to carry the increased loads and provide proper voltage 
regulation. 



On March 19 and 20, shortly after the new line was olaced in service, a 
severe sleet storm in the area between Dundalk and Orangeville caused heavy 



30 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

damage to telephone, telegraph and power lines. The excessive weight of sleet 
on wires and cables caused a number of breaks, particularly on the telephone 
lines, which hindered restoration of service. It was especially gratifying that the 
new line was completed prior to the sleet season as this storm would in all 
probability have caused serious damage to the old line. 

The 4,000-volt line between Grand Valley and Arthur was rebuilt. 
Approximately one hundred new poles were erected, the line was resagged, 
poles straightened and a number of guys added. 

Special inspection was made and defective crossarms, insulators and pins 
replaced on lines from Eugenia powerhouse to Collingwood, from Hanover to 
Chesley and Paisley, from Big Chute powerhouse to Waubaushene, from 
Waubaushene to Elmvale and from South Falls powerhouse to Huntsville. 

To conform with specifications of the Board of Railway Commissioners 
for Canada, the power lines at railway and telephone crossings were reinforced 
on line sections from Eugenia generating station to Owen Sound, from Eugenia 
generating station to Durham and Mount Forest, from Flesherton to Shelburne, 
from Fergusonvale to Collingwood, from Big Chute generating station to 
Waubaushene, from Waubaushene to Barrie and all south of Barrie, also all 
lines in Wasdells district. 

To accommodate changes in highway locations, a number of poles were 
moved or lowered between Kilsyth and Tara, between Waubaushene and 
Midland, between Waubaushene and Elmvale and between Barrie and Bradford. 

All poles in the section of transmission line between Gamebridge and 
Kirkfield and in all line sections of the Wasdells district south of Cannington, 
received treatment at the ground line with preservative. 

Over the whole system, 153 poles were reinforced by the addition of stubs 
and 21 poles were replaced. 

At Eugenia Falls plant, improvements were made in the station grounding 
to bring it up to standard and the 60-cell storage battery was replaced with a 
new battery. The timber in the trestle under No. 1 pipe line east of the surge 
tanks was replaced by the Operating department, and the Construction depart- 
ment placed a culvert under the No. 1 and No. 2 pipe line trestles along with 
a fill of rock, gravel and earth. Repairs were made to No. 3 unit draft tube 
quarter turn, also to the turbine runner and shaft. The work on the draft tube 
quarter turn and on the runner was done at the Commission's machine shop at 
Niagara Falls. This involved building up eroded sections by welding and altering 
the downstream clearance ring. A forged steel sleeve for the shaft at the stuffing 
box was supplied to replace the defective bronze sleeve and the necessary machine 
work was done at Eugenia Falls powerhouse. No. 1 and No. 2 turbines were 
also inspected but only minor repairs were necessary. 

At Walkerton generating station dam, repairs were made by the Construction 
department, which included the driving of sheet piling to form a cut-off wall to 
correct leaks under the centre portion of dam, provision of fills on the upstream 






1934 



HYDRO-ELECTRIC POWER COMMISSION 



31 



HORSEPOWER 



HORSEPOWER 



^5ini i§55iglSlSlig§i5i8I5lS i^glS§i8gglSilgl8J§i8lglSlll l5§§L 

30.000 -n M I I I I I I 1 I ' I 1 I I I I I I I I I I I 1 I I I I I I I I I I 1 I II I I | I | | i ll I M I 30.000 



25.000 



20,000 



15,000 



10,000 



5,000 




fsllliiilsl 



i8lllNiliigliSiiSi^isii§|igliii^ii§i§ 



NOTE: — The Georgian Bay system includes the Severn, Eugenia, Wasdells, Muskoka and Bala districts. 
In the diagram the load for the Muskoka, district is not included until November, 1924. Details 
respecting this load for preceeding years are given in earlier Annual Reports. The load of the 
new district at Bala is not included in above graph until April, 1931, previous meter records 
being incomplete 



side to prevent scouring, and the construction of rock-filled timber cribs on the 
downstream side at the east end of the dam, to divert the water and prevent a 
washout of the shore. While this work was proceeding, excessive flows developed 
in the river and required that a large flow be allowed to pass through the waste 
sluice at Walkerton plant. The action of the water started to scour the earth 
bank at the north-west corner of the powerhouse on the tailrace side. To protect 
the bank, it was necessary to construct a bench type timber crib with wood 
sheet piling on the side next the water. The crib was filled with rock and gravel. 

At Walkerton plant, which was shut down while repairs to the dam were in 
progress, an inspection was made of the turbines and hydraulic equipment and 
minor adjustment and repairs were made. The 2,300-volt tie line was rearranged 
to provide greater safety. 



32 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

At Hanover generating station dam, bad leaks developed at the junction of 
the old and new sections November 7, 1932. Examination revealed that pond 
water had scoured a channel under a bulkhead wall where it joins the north wall 
of the main sluice section. Repairs consisted of driving necessary piling to cut off 
any flow of water under the bulkhead, the underpinning of bulkhead to ensure 
its stability, erection of a protective crib, and the restoration of original fills. 
By agreement, this dam was later turned over to the town of Hanover as the 
town is interested in the maintenance of this dam to provide a supply of water 
for its pumping station. Water can still be secured for the operation of the 
Commission's hydraulic plant when required, limited only by the natural river 
flow, and a certain reserve for pumping plant operation. 

At Hanover generating station, repairs were made to the concrete wing 
wall on the north side of the intake canal adjacent to the plant. The concrete 
had become defective and excessive leaks developed. 

At Hanover frequency-changer station, operation for the past year was very 
satisfactory and no special maintenance work was required. 

At Big Chute generating station, the No. 1 transformer room and the low- 
tension room were painted. The field and armature coils of all machines were 
painted with insulating paint. No. 1 oil pump for supplying oil pressure to the 
governor system, which had given trouble, was redesigned, and after being placed 
in operation gave complete satisfaction. A number of decayed stop logs in the 
main dam were replaced with new logs. All hydraulic equipment was inspected 
and minor adjustments made. 

At Wasdells generating station, septic tanks and disposal beds for the 
superintendent's house and the generating station were constructed and the 
domestic water supply for the superintendent's house and powerhouse was re- 
arranged. In conjunction with this work, improvements to the grounds around 
the plant were carried out. The bearings in the No. 2 unit were removed because 
of wear and were rebabbitted. 

At South Falls generating station, owing to a failure of the screws holding 
the shaft cap, which in turn holds the thrust ring in place on the upstream end 
of No. 3 unit shaft, a change in design was decided upon and alterations were 
made to both No. 1 and No. 3 units, which are of similar construction, to guard 
against further trouble from this source. 

At Hanna Chute and Trethewey Falls generating stations, routine inspections 
of machines, buildings and water controlling structures were made, and only 
minor repairs were necessary. 

At Owen Sound distributing station, improvements were made to station 
grounding in order to bring the grounding layout up to standard. 

At Chatsworth distributing station, all 22,000-volt bus insulators were 
replaced, as they had given evidence of having served their useful life. 

At Shelburne distributing station, the high-voltage and low-voltage entrance 
structures were redesigned and a new airbreak switch was erected on the high- 
voltage line. Grounding connections were also improved. 



SAU3L £ /? f L 



FZNCTANG 

Q 



— Q MIDLAND M/DLAND , 



D D 



WINDZKMERZ HVN7SV/LL 






mj I i.soo I 
5 UW££»J- - A 




LEGEND 

[~~ j CEHERATINC_ STATIONS^ 

rXfl SWITCH ma STATIONS 

|C5xJ] EREQVEHCr CHANCER 

i | OISTRIBUTINC STATIO 

o 



vrj /« SERVICE 



GEORGIAN BAY SYSTEM 

(6Q CYCLES) 

DIAGRAM OF STATIONS 

AS AT OCTOBER 31. 1932 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



33 



At Berkeley distributing station, during a severe lightning storm on June 
7, one low-voltage and two high-voltage transformer bushings were destroyed; 
these were replaced with new bushings. 

At Kincardine distributing station, in order to provide for an increase in 
load due to a new power consumer, three 125-kv-a. transformers were removed 
and replaced with three 250-kv-a. transformers. 

At John E. Russell Company distributing station, Durham, one 150-kv-a. 
transformer failed in service October 16, and repairs were made at the manu- 
facturer's factory. 

Walkerton rural distributing station, which is located at Walkerton 
generating station, was placed in service October 20, 1932. This distributing 
station was completed January 24, 1932, but could not be placed in service 
until Mildmay distribution system was changed to 4,000 volts. 

At Gravenhurst and Huntsville distributing stations, improvements were 
made in grounding of equipment to bring grounding layouts up to standard. 



GEORGIAN BAY SYSTEM— LOADS OF MUNICIPALITIES, 1931-1932-1933 






Municipality 


Peak load in horsepower 


Change in load 
1932-1933 




Oct. 1931 


Oct. 1932 


Oct. 1933 


Decrease 


Increase 


Alliston 


199.6 
130.7 
121.0 
2,503.4 
295.6 

134.7 
138.2 
59.0 
290.0 
155.5 

51.7 
406.9 
290.9 

1,458.3 
52.5 

107.2 
145.1 
627.3 
145.4 
63.8 


227.9 
128.9 
118.0 
2,381.1 
216.4 

106.6 
134.9 
56.3 
320.0 
161.9 

53.2 

407.5 

257.3 

1,339.9 

59.0 

121.4 
148.8 
392.1 
147.4 
65.1 


198.0 
132.7 
120.0 
2,195.6 
179.7 

114.3 
140.0 
45.4 
263.4 
152.8 

61.2 

464 

234.6 

1,293.8 

52.9 

96.0 
163.0 
712.3 
148.8 

51.3 


29.9 




Arthur 


3.8 


Bala 


«$ 


2.0 


Barrie 


185.5 
36.7 




Beaverton 




Beeton 


7.7 


Bradford 




5.1 


Brechin 


10.9 

56.6 

9.1 




Camp Borden 




Cannington 




Chatsworth .... 


8 


Chesley 




56.5 


Coldwater 


22.7 

46.1 

6.1 

25.4 




Collingwood 




Cookstown 




Creemore 




Dundalk 


14.2 


Durham 




320.2 


Elmvale 




1.4 


Elmwood 


13.8 





34 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



GEORGIAN BAY SYSTEM— LOADS OF MUNICIPALITIES, 1931-1932-1933— Continued 



Municipality 



Peak load in horsepower 



Oct. 1931 Oct. 1932 Oct. 1933 



Change in load 
1932-1933 



Decrease Increase 



Flesherton 

Grand Valley . . . . 

Graven hurst 

Hanover 

Hepworth 

Holstein 

Huntsville 

Kincardine 

Kirkfield 

Lucknow 

Markdale 

McTier 

Meaford 

Midland 

Mildmay 

Mount Forest . . . 

Neustadt 

Orangeville 

Owen Sound 

Paisley 

Penetanguishene . 

Port Carling 

Port Elgin 

Port McNicoll.. . 
Port Perry 

Priceville 

Ripley 

Rosseau 

Shelburne 

Southampton 

Stayner 

Sunderland 

Tara 

Teeswater 

Thornton 

Tottenham 

Uxbridge 

Victoria Harbour 
Victoria Road . . . 
Walker ton 

Waubaushene. . . 

Wiarton 

Windermere 

Wingham 

Woodville 



87.0 


121.1 


622.0 


1,002.7 


24.1 


20.9 


1,023.5 


434.8 


31.0 


222.5 


163.3 


148.0 


431 6 


2,723.7 


63.1 


358.4 


33.5 


550.3 


3,202.4 


113.1 


552.3 


126 .0 


195.7 


99 


211.9 


15.7 


55.4 


30.0 


235.8 


233.2 


193.7 


59.0 


84.1 


134.8 


23.4 


55.7 


199 8 


64.3 


10.3 


492.2 


52.9 


238.3 


25.0 


304.6 


65.1 



79.8 

123.8 

574.0 

1.042.9 

24.1 

18.7 

1,047. C 

407 . 5 

28.6 

187.0 

149.4 
145.0 



394 

3,345 

66 



328.4 

30.0 

621.0 

3,338.5 

114.4 

561.1 
128.0 
201.8 
90.2 
179.8 

16.0 

58.9 

35.1 

197.9 

235.9 

203.2 
63.0 

87.7 

114.9 

18.3 

64.3 

205.8 

76.4 

10.0 

419.9 

58.3 
220.1 

31.0 
209.3 

61.0 



75.9 


3.9 

15 5 




108.3 




672.5 


98.5 


910 4 


132 5 




25.7 


1.6 


16 6 


2.1 
91 2 




955 . 8 




564.3 


156.8 


22.8 


5.8 




222.5 


35.5 


179.4 




30.0 


111.0 


34.0 




395.4 


0.7 


2,408.6 


937 




71.5 


4.8 


329.5 




1.1 


34.0 




4.0 


585.4 


35.6 
261.5 




3,077.0 




118.6 


4.2 


658.7 




97.6 


105 


23.0 




262 . 5 


60.7 


83.5 


6.7 
23.2 




156.6 




16.7 


0.7 


60.3 




1.4 


30.0 


5.1 

5.0 

30.0 

33.9 
3.0 
5.5 
2.5 
0.4 

2 1 

3.6 




192.9 




205.9 




169 3 




60.0 




82.2 




112.4 




17 9 




62.2 




202.2 

77.3 


"0.9' 


10.0 






463.1 




43.2 


56.3 
232.2 


2.0 


12 r 


33.0 




2.0 


290.5 




81.2 


55.2 


5.8 





Note: Formosa absorbed by Bruce R.P.D. 

Hornings Mills absorbed by Shelburne R.P.D. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



35 



GEORGIAN BAY SYSTEM 


-RURAL POWER DISTRICT LOADS, 1931-1932-1933 


Rural power district 




Peak load in horsepower 


Change in load 
1932-1933 




Oct. 1931 


Oct. 1932 


Oct. 1933 


Decrease 


Increase 



Alliston. . . 


92.2 

3.2 

56.0 

196.3 


107.1 
3.2 

61.0 
220.7 

36.2 

85.8 

157.3 

2.0 

46.7 

61.1 

13 . 
44.0 
10.3 
0.8 
56.2 

72.4 
7.3 
37.2 
84.1 
20.0 

162.2 

151.4 

20.9 

17.0 

19.0 

30.3 
33.1 
10.0 
121.8 
10 

8.8 

21.1 

119.8 

54.0 

12.7 

35.0 

104.5 

92.5 

99.5 


69.3 

3.2 
93.0 

233 4 

45.5 

110.0 

137.6 

5 

42.8 

103.3 

12.0 

35.7 

8.9 

0.8 

55.0 

66.3 
8.0 

27.7 
93.4 
48.2 

191 7 

136.2 

33.4 

21.0 

21.0 

28.1 
34.9 
53.0 
141.0 
10 3 

12.3 
29.3 
124.1 
50.0 
16.3 

43.9 
105.1 
114.6 
106.2 


37.8 




Arthur 




Bala 




32.0 


Barrie 


19^7 


12.7 


Baysville 


9.3 


Beaumaris 


83.1 
47.2 


24.2 


Beaverton 




Beeton 


3.0 


Bradford 


20.0 
50.3 

12.0 

41.5 

9.8 

0.8 

20.1 

63.2 
5.5 
32.1 
56.3 
14.0 

135.4 

151.4 

2.0 

11.0 

14.0 

29.6 

35.5 

8.0 

103.1 

10.0 

8.0 

9 6 

98.4 

45.7 

12 

24.0 
102.5 

76.0 
104 2 


3.9 




Bruce 


42 2 


Buckskin 


1.0 
8.3 
1.4 




Cannington 




Chatsworth 




Cookstown 




Creemore 


1.2 
6.1 




Elmvale 




Flesherton 


0.7 


Gravenhurst 


9.5 




Hawkestone 


9.3 


Huntsville 




28.2 


Innisfil 




29.5 


Mariposa : 


15.2 




Markdale 


12.5 


Medonte 




4.0 


Midland 




2.0 


Nottawasaga 


2.2 




Orangeville 


1.8 


Owen Sound 




43.0 


Port Perry 




19.2 


Ripley 


0.3 


Sauble 


3.5 


Shelburne 




8.2 


Sparrow Lake 




4.3 


Tara 


4.0 




Thornton 


3.6 


Utterson 




8.9 


Uxbridge 




0.6 


Wasaga Beach 




22.1 


VY roxeter 




6.7 









Note: Georgina R.P.D. absorbed by Beaverton R.P.D. 

Cannington R.P.D. includes what was formerly known as Cannington R.P.D. No. 
1 and No. 2 districts. 



36 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 



EASTERN ONTARIO SYSTEM 

The load on the Eastern Ontario system continued at a slightly lower level 
during the earlier months of the fiscal year. However, beginning with the month 
of April, a gradual improvement began and continued until the end of the year. 
The peak demand for the month of October exceeded the peaks for the corres- 
ponding months of 1931 and 1932 and almost equalled the peak of 1930 which 
is the maximum peak on record for this month. The kilowatt-hours used in 
the month of October are the maximum recorded for the month of October in 
any year. 

District Load Conditions 

In the Central Ontario district the load showed signs of an underlying 
improvement about the end of February, the downward trend of the load being 
less than usual for the season. During subsequent months the improvement 
became more evident. By June the load had recovered all lost ground, and 
thereafter continued to exceed the loads of the corresponding months of the 
previous year, with a slight exception in September. The peak load for the 
month of October shows an increase of more than six per cent over, the peak 
for the corresponding month of 1932. 

A survey of the municipal and industrial loads in this district indicates a 
rising tendency during the latter months of the year. It should be noted that 
one large industrial customer who was taking a load of more than 3,000 horse- 
power in October, 1932, has not operated throughout the year 1933. If this 
customer is left out of consideration when analyzing the load trend in the 
remainder of the district, it will be evident that there has been a definite 
improvement in load conditions in the Central Ontario district during the 
latter part of 1933. 

The Ottawa district load maintained approximately the same level on peak 
as in 1932 until early in September when the load showed a slight increase which 
continued into October. The monthly average loads show a slight decrease but 
approximate those of the two previous years. It will be noted that the monthly 
peak loads in this district have continued to show, with few exceptions, increases 
over the corresponding months of the previous years. This is primarily due to 
the fact that the industrial load, which has suffered the greatest losses as a result 
of the depression, represents only a small percentage of the total load in this 
district. It also indicates that the residential and commercial load has made 
increases which more than off-set any industrial decreases. 

The St. Lawrence district load was someuhat irregular during the earlier 
months of the year, but was consistently higher than the 1932 peak loads after 
the month of March. The 1933 peak-load curve crossed the 1931 curve early 
in the month of July and continued to show an increase until the end of the 
year. The peak demand for the month of October exceeded the maximum 
monthly peak on record for this district. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



37 



HORSEPOWER 



1 

JAN ' 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 

SEPT 
OCT 

NOV 

DEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE. 

JULY 

AUC 

SEPT 

OCT 

NOV 

DEC 

FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUC. 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 

SEPT 
OCT 
NOV 
DEC 


IDU.UUU 






















1QOO f* . / \ #■-» 


1933 / > r \_. / \ . / "\ 


\....jr s ..„ /-—ji\t—- _:-:\ y L__p = P i_ 


<^-'>? i - '>-■>/ * w v \/ 


^ J- loon. 1Q^1 -1Q^9 


^ / iyju iyji ii7o£ 


Trr i yzy 

1 q on 


i y^o 










EASTERN ONTARIO SYSTEM _ _ 




PEAK LOADS 


FOR ALL DISTRICTS COMBINED 






HYDRO-ELECTRIC POWER COMMISSION 


I I ! I II I I I I I l II II I II I I I I I I ! ! I I II I I 


e 

JAN 
FEB 

MAR 
APR 
MAY 
JUNE 

AUG 
SEPT 
OCT 
NOV 
DEC 

FEB 

MAR 
APR 

JUNE 

AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 

JUNE 

AUG 
SEPT 
OCT 
NOV 
DEC 

FEB 

APR 
MAY 
JUNE 

AUG 
SEPT 
OCT 

DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 

AUG 
SEPT 
OCT 
NOV 
DEC 



HORSEPOWER 



I50.0CO 



100,000 



50,000 



The monthly average loads on the St. Lawrence district showed a slight 
decrease during the months of January and February in comparison with the 
corresponding months of 1932, but were almost identical with those of 1931. 
However, the average load for the month of March exceeded the average load 
recorded during any previous month, and the load continued to increase until 
the end of the year. While certain of the municipalities and industrial customers 
show an increase on both peak and average load, one large industrial customer 
was chiefly responsible for the increase shown by the district as a whole. 

The Rideau district has maintained approximately the same levels on both 
peak and average loads as in 1931 and 1932. 



The Madawaska district load conditions were slightly below the 1932 level 
during the earlier months of the year but made a recovery in the early part 
of July and continued to show a slight increase until the end of the year. 



38 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 




HYDRO- E.H.CTR1C POWE.R C0MM155ION OT ONTARIO 

Graphs Shewing 
PRECIPITATION on she OTONABK WATERSHED 
1933 



TK* Actual sad Normal 

Ike oumtritel lol*k of t»iui 

Dm Normal Rttipl^hcp far 



iptoijon [*aur»j thown in 111' 
[mm lii» t»ur jletiom 
Jk Month H the wttttt 



jrc: 

OVtr a period <f y*0r>. 

TV* Upper Oreoi e»mi« Ike Ach»! Mwtilly FWctptisW it a fcseaiaqt 

of Ik. Normal PretlpSl.llon f«r ttiel nonlh «nd .« Int msrlMy oemwk differ, 

ff does ftd relate fcne meuln fo enoiher. 

TK. tower Graplu iU tke Adtwl and NotmiI R-rtij>iWfcm m tocbes »f rain. 



% 80 



60 



40 



20 



■~7T 



.05. PIBCgNX. <K_HSSMAL. 



160 



140 



120 



W& too 



*F\ 



'eruniafie of Normal rVecipila}i< 



80 % 
I 

60 1 

-40 Z 

'C 

j 

20. . 



014 
12 
10 



inches (Nornwi) Prsdpiiatior. 







14. 



Iticheft (Actual) Precipitation 



stations:- t- Ptterbonj 

2- Lindsay . 

3- Ap»l«y 

4- Bancroft 



Mi 



1933 Jan. Feb. Mar. Apr- j May I Jun* July ; Auo,. \ Septr Oct j Nov. 



Dtc. 1933 i 



PLATE A— PRECIPITATION DATA— 1933 

The upper graph represents the estimated actual monthly precipitation on the Otonabee 
watershed expressed as a percentage of the normal precipitation. 

The estimate is based upon the actual and normal return of the Meteorological Service 
for Peterboro, Lindsay, Bancroft and Haliburton. 

Although the numerical values differ from month to month the normal precipitation is 
taken as 100 per cent, hence the solidly hatched areas represent the amount by which the 
precipitation exceeded the average while the dotted hatched area represents in a similar 
manner the deficiencies. 

The lower graph shows the actual and normal precipitation in inches of rain 



Graph No. 3— Average daily wastage at all H.E.P.C. plants. In the weekly aggregate the area under 
this graph equals the wastage represented by the dotted hatched area between curves 
2 and 1a. 

Graph No. 5 — Midnight elevations of Rice Lake. 

Graph No. 6— Midnight elevations of Heely-Hastings reach. 

*Operating week changed to end Sunday midnight instead of Friday midnight. The period shown 

ending December 1st covers two days only. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



39 



If- 



3WO- £l£GTb t Q .°i3fv'«? ' C0Ma4>33IOK.. Or ov: 
■■CJuhaf : Onttrric Qisfrlil- 



VOLS' „ 






»i.*j|| 






j»i iJua.. 







if* 
S'l 
III 

pi 






j: ■ \ 
sdo-o.io.c .1 












III 


>99 a; t'6. J ', 






-■ v 




/\ 


yvj. ; 




f: . : f| 


' ■ V 










fcacoa ._ 









f y 




■;MC£ lA^t 3.£WT«ShS 



W a W^^vv^:- 




piUiffii-j 



13 



f* 



mi 






ssus » * i « is i! w } tt 



» 2J *> 7 14 It 2S 
Apr- . , [MdJ- ; 



•5 I » K 3 K i B •» 77 t 'J B H 
.'\toty Au^t Sepfc 



XI 29 5 S 19 ' -J* "3 B «9f 



PLATE B— GENERAL OPERATING DATA 

December 16, 1932, to December 20, 1933 

Notes for Eastern Ontario District General Operating Data Curves 

Graph No. 1 — System average weekly load in kilowatts which includes power purchased from the 

Gatineau Power Company. 
Graph No. 1a — Weekly average load in kilowatts supplied by H.E.P.C. plants on the Trent and 

Otonabee rivers. 
Graph No. 2 — Weekly average power equivalent of total flow at all H.E.P.C. Plants. This equals the 
weekly average load supplied by these plants, plus the power equivalent of the weekly 
average wastage at these plants. This wastage is shown by the dotted hatched area 
between curves 2 and 1a. 

{Explanation continued on page 38, facing) 



40 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Stream Flow — Trent River 

Stream flow in the Trent river, from which the Central Ontario district 
obtains the greater part of its power supply, showed a heavy surplus over power 
requirements during the first seven months of the fiscal year due to the heavy 
precipitation experienced in the late summer and fall of 1932, and during the 
first part of the winter months of 1932-33. However, from the beginning of 
May, 1933, until the end of October, rainfall was consistently below normal, 
excepting the month of August, with the result that very critical periods 
of low stream flow were experienced during the months of September and 
October. Some of the weekly average flows experienced during this time 
were even lower than those experienced in 1931, and represent the lowest 
on the Commission's records, which date back to 1916. The capacity of 
the Commission's generating stations on the Trent river was very seriously 
reduced during these periods of low stream flow. The weekly average available 
capacity of these generating stations during the week of minimum stream flow 
amounted to only 11,720 horsepower, and this, in terms of the district weekly 
load factor, gives a peak capacity of 18,000 horsepower, or a reduction in peak 
capacity of approximately 35,000 horsepower. Serious load reductions would 
have had to be made had not the supply of Gatineau power been available. 



Generating Stations 

Continuing the same plan of operation followed in 1932, as mentioned in 
the previous issue of this Report, Plant No. C-30 at Fenelon Falls and Plant 
No. C-5 at Frankford in the Central Ontario district, and Galetta generating 
station in the Madawaska district, were maintained throughout the year on a 
standby basis. 

During the year the usual programme of station and line maintenance 
work was carried out. An outline of the work done is given in the following 
paragraphs. 

At Sidney, plant No. C-2, the four main turbines and the exciter turbine 
were unwatered. Inspection indicated that no extensive maintenance work was 
necessary. The lower guide bearings on two of the main turbines were rebabbitted. 
All governors were dismantled and thoroughly cleaned ; defective bearings being 
replaced where necessary. All the low-tension oil-breakers were overhauled. 
Three defective bushings were replaced on one of the generator 10,000-volt 
oil-breakers. The direct-current cables to all generators were replaced. All the 
power-house floors and the walls and ceiling of the thrust deck were painted. 
The entire roof of the power house was treated with a roofing compound. 

At Frankford, plant No. C-5, no extensive maintenance work was found 
necessary. One turbine was overhauled. The low-tension electrolytic lightning 
arresters were overhauled. The core wall between the tail race and the river 
was repaired. This plant was maintained on a standby bass during the year 
and was only placed in operation on occasions when the additional capacity was 
required. 



1934 HYDRO-ELECTRIC POWER COMMISSION 41 

At Meyersburg, plant No. C-8, all turbines were unwatered and inspected 
and the racks were cleaned. The governors were overhauled and painted. All 
the high-tension oil-breakers were overhauled. One defective 44,000-volt bushing 
was replaced in the station service oil-breaker. 

At Hagues Reach, plant No. C-9, all turbines were unwatered and inspected 
and the racks were cleaned. The bearings of one turbine were tightened. A 
quantity of debris was removed from the wheel pits. The governors were 
overhauled and painted. One of the 1,350-kv-a. 44,000-volt transformers failed 
in service on July 7. Tests and inspection showed that one of the high-tension 
coils in one phase had failed, and the complete section of winding was returned 
to the manufacturer for repairs. Following repairs this transformer was again 
placed in service on August 28. All the high-tension oil-breakers were overhauled. 
A defective 44,000-volt bushing was replaced on one of the station service 
transformers. 

At Ranney Falls, plant No. C-10, the forebay was unwatered and the racks 
were cleaned. The governors were overhauled and painted. A new 58-volt 
storage battery was installed, replacing the defective battery used in connection 
with the supervisory remote control equipment. Current transformers were 
installed in the neutrals of each of the 4,500-kv-a. generators for protective 
purposes. The high-tension oil-breakers were overhauled. All connections to 
the 6,600-volt buses were overhauled. The generator room floor, steel window 
sash and the low-tension gallery floors were painted. 

At Seymour, plant No. C-ll, the forebay was unwatered and the racks 
were cleaned. The exciter turbine and two of the main turbines were overhauled. 
On one of the turbines the crown gear, countershaft and bearings had to be 
replaced. All the governors were overhauled. The high-tension oil-breakers and 
electrolytic lightning arresters were overhauled. The armature of the turbine 
exciter failed in service and was returned to the manufacturer where it was 
rewound. Disconnecting switches were installed on the bus side of two of the 

low-tension feeder oil-breakers. 

♦ 

At Heely Falls, plant No. C-14, the turbines were unwatered and inspected 
but no extensive maintenance work was found necessary. The glands on each 
turbine were repacked. The screen on the Pelton wheel of one unit was cleaned 
and the debris was removed from the pit of another unit. The racks in front 
of the penstocks were cleaned. Three new 44,000-volt side-opening disconnecting 
switches were installed on one of the main transformer banks. The high-tension 
and low-tension oil-breakers and lightning arresters were overhauled. Extensive 
painting was carried out on the floors, walls, ceilings and steel window sash in 
the control room, in the low-tension galleries and on the low-tension cell structures. 

At Auburn, plant No. C-18, the forebay was unwatered and the racks were 
cleaned. The walls of the forebay were inspected. One turbine was overhauled. 
All the coils in each generator were examined and tightened, and all generators 
were thoroughly cleaned and painted. The low-tension electrolytic lightning 
arresters were overhauled. 



42 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

At Fenelon Falls, plant No. C-30, the turbines were unwatered and com- 
pletely overhauled. On one turbine a new set of 24 gate connecting rods was 
made up and installed. New pins were installed in the regulating ring. The 
gate stem shaft bearings were bored out and bushed, and a new gate stem shaft 
was installed. On the second turbine 24 new gate bolts were installed in the 
regulating ring and all the worn holes in the gate arms were welded. One of 
the 400-kv-a. generators failed in service under normal operating conditions on 
September 9. Approximately 60 coils were completely destroyed, 100 coils 
were damaged and a section of the lamination which forms the coil slots was 
badly burned. This generator has been in service for more than thirty years, 
and the cause of the failure was undoubtedly due to deterioration of the insulation 
on the bars. This machine will be completely rebuilt following reinsulation of 
all the coils by the Commission's Service Department. A broken section of the 
power house wall on the side next to the river was torn out and rebuilt. 

At High Falls generating station on the Mississippi river the gate operating 
mechanism of one turbine was completely overhauled. Due to some obstruction 
the gate spindle in the gate house was bent when lowering the gate, but satis- 
factory repairs were made by the Commission's maintenance staff. 

At Calabogie generating station on the Madawaska river one of the main 
turbines and the exciter turbine were unwatered and inspected but no extensive 
maintenance work was found necessary. The 33, 000-volt and 6,600-volt electro- 
lytic lightning arresters were completely overhauled. All interior and exterior 
woodwork was painted. The lower layer of brick along the tail race wall was 
renewed up to the sills of the lower windows. 

At Galetta generating station on the Mississippi river, one turbine was 
unwatered for the purpose of making minor repairs and adjustments. The 
11, 000-volt electrolytic lightning arresters were overhauled. 



Municipal, Distributing and Switching Stations 

At Auburn transformer station the high-tension oil-breakers and electrolytic 
lightning arresters were overhauled. One defective 44, 000-volt oil-breaker 
bushing was replaced. 

At Belleville switching station all the high-tension oil-breakers were 
overhauled. New fences were built enclosing the station property and the switch 
structures. The station site was greatly improved by grading. 

At Belleville distributing station No. 1, a chain link fence was built partially 
enclosing the station property. The station site was improved by grading. 

At Colborne distributing station new insulators were installed on the 
44, 000-volt lightning arrester horn gaps and new conductor was installed between 
the horn gaps and the 44, 000-volt inlet bushings. A defective low-tension lightning 
arrester was replaced on the Colborne feeder. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



43 



HORSEPOWER 



HORSEPOWER 



40.000 



30.000 



20.000 



10.000 



j8insgSS§i8g6iniis5§i8llgilIgi§S5ig|isllliiiS5§gi5lSlii§65i8 



i i i i i i i 1 1 i i i i i i i i 
EASTERN ONTARIO SYSTEM 

OTTAWA DISTRICT 

PEAK LOADS 



HYDRO ELECTRIC POWER COMMISSION 
OF ONTARIO 




isiIIiilS§§g|l5iiIill5§i8isiilSiiS§iSisiilSil5§IgssilIiil6§i8 



40.000 



30.000 



20.000 



10.000 



At Cobourg distributing station the high-tension and low-tension oil- 
breakers were overhauled. A new 24-volt storage battery with trickle charger 
was installed to supply tripping potential for the high-tension and low-tension 
oil-breakers. A new gravity balance graphic wattmeter was installed to record 
the load of Cobourg and the existing solenoid type graphic wattmeter was 
reconnected with the necessary r-kv-a. resistances for recording the r-kv-a. 
load. Individual phase ammeters were installed on all the low-tension feeders 
and on the two transformer panels. All the electrical equipment was phase 



44 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



Renfrew cist srsTEAf 



33,000 V 



S400 

HORSfPOWSR 



D 



-#• RENFREW R>P D 
RENFREW 



33, OOP V 



A 'RN PRIOR RURRL SYSTEM 
—+- 3RRES/OE 
ARN PRIOR 

galctta 



33,OOOK 



CRATS FALLS 
■^-CONSTRUCTION 
STATION. 
(DISMANTLED) 



a 



CRLRBOGiE DIST. SYSTEM 



1070 
HOffSEPOWEI 
T 



KINGDOM MINE 



RR'K/P'/P/OR *>.*£>. 



LEG EN'D 



□ 



GENERATJNG STATIONS 

("HORSEPOWER" 15 RATED ELECTRICAL 
HORSEPOWER AT RATED POWER FACTOR) 

TRANSFORMER STAF/OAAS 

D/5TRI3L>rt/VC: STATIONS 

STATIO/VS AND L/AIES //V SERVICf 

STATIOAIS AND ll/VES IVOT COMMISSIONS PROPFRry 



EASTERN ONTARIO SYSTEM 

MADAWASKA DISTRICT 

(60 CYCLES) 

DIAGRAM OF STATIONS 

AS AT OCTOBER 3!. 1933 



marked and the low-tension transformer connections were rearranged so as to 
make them standard phasing. The switchboard was rewired. The ceiling, floors, 
and steel window sash were painted. 

At Kingston switching station the high-tension oil-breakers were overhauled 
on two occasions. 



At Kingston distributing station the 750-kv-a. transformer was replaced by 
a 1,500-kv-a. transformer, increasing the capacity of this station to 4,500-kv-a. 
The high-tension oil-breaker was overhauled and painted. Insulating couplings 
were installed in the transfer device of the 44,000-volt electrolytic lightning 
arresters. A new ground conductor was installed between the high-tension 
lightning arresters and the water main. 

At Madoc distributing station the high-tension and low-tension oil-breakers 
and the 44,000-volt electrolytic lightning arresters were overhauled. Two 
defective 5 kw. bucking transformers were replaced on one of the low-tension 
feeders. A chain link fence was built enclosing the substation. 

At Maxville a new 44,000-volt 225-kv-a. distributing station was constructed 
and placed in service on November 20, 1932. Previous to this date Maxville 
and the Maxville rural power district obtained power at 4,000 volts from the 
150-kv-a. transformer at Apple Hill. 



FALLS \hORS£PO"£*\ 



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"pi ! * m K.KD° 

L r 7 ^" 



KEMPTYILLE R R D. 



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1934 HYDRO-ELECTRIC POWER COMMISSION 45 

At Oshawa No. 1 distributing station the high-tension oil-breakers were 
overhauled on two occasions. The low-tension oil-breakers were overhauled 
once. All electrical equipment was phase marked. The station site was improved 
by grading and filling in the low areas at the back of the property. The station 
floors were all painted. 

At Oshawa condenser station the bearings of the 5,000-kv-a. condenser 
were inspected and cleaned. The collector rings were ground and polished. The 
starting switch of the 75-h.p. motor was overhauled. A new endless belt was 
installed on the exciter of the 1,000-h.p. condenser. The steelwork, crane and 
floors were painted. 

At Ottawa 110,000-volt transformer station a defective bushing was replaced 
on one of the 110,000-volt oil-breakers. Defective supports were replaced on 
the 110,000-volt bus structure. A graphic instrument was installed at this 
station whereby a remote record is obtained of the total power supplied to the 
Commission by the Gatineau Power Company under the 60-cycle contract. 
The instrument transformers, thermal converters, etc., used in connection with 
this metering equipment, are installed at the Gatineau Power Company's 
terminal station at Valtetreau. 

At Picton distributing station defective insulators and pins were replaced 
on the 44,000-volt bus. The 44,000-volt air-break switch was overhauled. The 
transformers were inspected and painted. A coat of roofing compound was 
applied to the station roof. The property fence was painted. 

At Port Hope switching station all the high-tension oil-breakers were over- 
hauled on two occasions. 

At Port Hope distributing station the high-tension and low-tension oil- 
breakers were overhauled. Defective lightning arresters were replaced on two 
of the low-tension feeders. 

At Sidney terminal station the high-tension oil-breakers and high-tension 
electrolytic lightning arresters were completely overhauled. All the old pin-type 
insulators were replaced on the outdoor high-tension structures. The old station 
roofing was completely removed and replaced by three layers of three-ply felt, 
each layer being rolled in hot asphalt. A coat of roofing compound was applied 
to the roof of the lightning arrester annex. The station floors were painted. 

At Smiths Falls transformer station the two 1,250-kv-a. single-phase trans- 
formers and the 1,500-kv-a. three-phase transformer which failed in service on 
August 27, 1932, were repaired and again placed in service on November 6, 1932. 
The tap leads on the remaining two 1,250-kv-a. transformers were reinsulated 
to prevent the possibility of similar trouble damaging these transformers. 

At Williamsburg distributing station a second 100-kv-a. 44,000-volt single- 
phase transformer was installed and placed in service on March 15. 

At Wellington distributing station the 44,000-volt air-break switch was 
overhauled. The 300-kv-a. transformer was thoroughly cleaned and painted. 
The station floor and the property fence posts were painted. A coat of roofing 
compound was applied to the station roof. 



46 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



High-Voltage Transmission Lines 

Work in connection with the inspection and maintenance of high-voltage 
transmission lines was actively carried out during the year. Approximately 
38,000 pin-type insulators were inspected, and 1,400 were found defective and 
replaced. Approximately 10,000 poles were examined, of which over 900 were 
found defective at the ground line and were stubbed. A considerable number of 
poles were straightened and reset. Defective crossarms and timbers were replaced 
where necessary. Approximately 8,800 poles were treated with a chemical pre- 
servative. The usual programme of tree trimming and weed cutting was carried 
out on various high-tension line sections. Defective power and telephone 
conductors were replaced where necessary. A number of highway, railway and 
foreign wire crossings were rebuilt to conform with present-day requirements. 
Approximately 600 feet of defective twenty-pair telephone cable was replaced 
between plants No. C-9 and No. C-10. This cable is used in connection with 
the operation of the supervisory remote-controlled plants No. C-8 and No. C-9 
which are controlled from plant No. C-10, Ranney Falls, near Campbellford. 

Meter Department and Repair Shops 

The usual programme of routine work in connection with the maintenance 
of metering and relay equipment was carried out by the Meter department. 
A series of special ground resistance tests were made at a number of stations 
with a view to improving the high-tension neutral and high-tension arrester 
grounds. Tests were also made on several of the station low-tension metering 
grounds, and on station fences, etc., with a view to removing any possible hazard 
due to potential gradients. Improvements were made at a number of stations 
through the co-ordination of the high-tension and low-tension fuses. Phase 
marking of high-tension lines and equipment was carried out at a number of 
stations. 

This department is available on request to any of the municipalities in 
connection with the investigation of technical problems in the field. 

The Belleville machine and meter repair shop has continued the usual 
programme of testing and repairing the various types of service meters for 
municipal and rural systems. A certain amount of work was also carried out in 
connection with repairs and replacement parts for hydraulic and electric 
apparatus. 

EASTERN ONTARIO SYSTEM— LOADS OF MUNICIPALITIES— 1931-1932-1933 





Municipality 


Peak load in horsepower 


Change in load 
1932-1933 




Oct. 1931 


Oct. 1932 


Oct. 1933 


Decrease 


Increase 


Alexandria 




184.5 
28.0 
74.2 


212.9 

30.1 

82.4 

23.4 

3,701.4 


227.7 

32.4 

74.4 

29.2 

3,786.6 




14.8 


Apple Hill. 






2.3 


Athens 


8.0 




Bath 


5.8 


Belleville 


3,687.5 




85.2 









1934 



HYDRO-ELECTRIC POWER COMMISSION 



47 



EASTERN ONTARIO SYSTEM— LOADS OF MUNICIPALITIES— 1931-1932-1933 

— Continued 



Municipality 



Peak load in horsepower 



Oct. 1931 Oct. 1932 Oct. 1933 



Change in load 
1932-1933 



Decrease Increase 



Bloomfield . . 
Bowmanville 
Brighton .... 
Brockville. . . 
Cardinal. . . . 



Carleton Place 
Chesterville . . . 

Cobourg 

Colborne 

Deseronto 



Finch 

Hastings. . . 
Havelock . . 
Kemptville 
Kingston . . . 



Lakefield . 
Lanark. . 
Lancaster 
Lindsay. . 
Madoc. . . 



Marmora . . 
Martintown 
Maxville. . . 
Millbrook. . 
Napanee 



Newburgh . . . 
Newcastle. . . . 
Norwood 

Omemee 

Orono 

Oshawa 

Ottawa 

Perth 

Peterborough 
Picton 

Port Hope. . . 

Prescott 

Richmond. . . . 

Russell 

Smiths Falls. . 

Stirling 

Trenton 

Tweed 

Warkworth. . . 
Wellington . . . 

West port 

Whitby 

Williamsburg. 
Winchester . . 



87.8 


1,551.4 


284.8 


2,271.2 


131.3 


848.5 


197.7 


1,468.6 


182.3 


146.8 


38.9 


73.7 


227.9 


241.9 


4,580.0 


227.7 


61.8 


62 9 


1,718.9 


165.7 


89.2 


26.1 


72.6 


68.9 


1,015.2 


41.0 


82.5 


135.3 


76 6 


58.5 


7,369.9 


24,841.8 


1,069.1 


6,158.4 


887.4 


1,108.0 


815.5 


39.4 


57.9 


1,597.9 


265.1 


2,874.1 


189 9 


75.8 


205.9 


1,028.5 


69.7 


216.4 



73.4 


1,546.2 


270.7 


2,380.1 


139.7 


966.5 


191.1 


1,424.7 


163 6 


148.6 


42.3 


65.2 


175.6 


241.3 


5,105.2 


209.7 


64.7 


33.6 


1,564.5 


153.6 


85.8 


21.5 


80.4 


79.6 


935.2 


42.6 


64.2 


116.3 


77.4 


78.3 


6,494.6 


5,758.6 


1,038.9 


6,011 4 


871.6 


1,081.9 


770.8 


45.9 


42.6 


1,509.3 


239.9 


2,745.4 


169.2 


67.7 


191.7 


65.1 


1,009.4 


142.1 


235.7 



76.1 


1,528.8 


279.9 


2,329 1 


142.3 


1,030.8 


159.9 


1,501 3 


126.8 


118.5 


44.9 


73.9 


131.3 


246.2 


5,429.6 


223.8 


71.8 


43.8 


1,760.1 


152.1 


84.7 


21.8 


85.2 


75.6 


978.7 


45.6 


101.0 


96.1 


97.7 


78.6 




6,722.5 


26,208.0 


1,135.4 


6,407.7 


869.8 


1,149.1 


696.5 


47.4 


51.1 


1,468.4 


213.1 


2,911.1 


145.9 


73.4 


167.5 


69.4 


987.9 


198.4 


231.5 



17.4 
5L0 



31.2 



36.8 
30.1 



44.3 



1.5 
1.1 



4.0 



20.2 



1.8 

74'3 

40'9 
26.8 
23 . 3 ' 
24.2 

21.5 
4*2 



2 


7 


9 


2 


2 
64 


6 

3 


76 


6 




2 
8 


6 
7 



4.9 

324.4 

14.1 

7.1 

10.2 

195.6 



0.3 

4.8 



43.5 

3.0 
36.8 

20.3' 
0.3 

227.9 

449.4 

96.5 

396.3 



67.2 

L5 
8.5 



165.7 
"5.7 

4.3 
56.3 



48 



TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 



EASTERN ONTARIO SYSTEM— RURAL POWER DISTRICT LOADS, 1931-1932-1933 



Rural power district 


Peak 1 


oad in horsepower 


Change 
1932- 


in load 
1933 




Oct. 1931 


Oct. 1932 


Oct. 1933 


Decrease 


Increase 


Alexandria 


25.0 
281.6 
160.4 

16.8 
269.0 

58.9 

184.5 

220.3 

77.0 

20.0 

415.5 
13.4 

265.7 

10.0 

4.0 

62.5 
118.4 

31.9 
145.8 
563.8 

61.7 
21.0 

3.0 
667.1 

3.0 

476.4 

92.0 

46.2 

211.0 

139.0 

3.0 

169.7 
32.8 


30.4 

304.0 

97.3 

22.8 
288.1 

67.3 
186.2 
242.9 

94.2 

47.2 

445.0 
18.1 

296.2 
32.7 
10.0 

53.4 
156.0 

34.3 
177.2 
624.3 

72.6 

27.9 

3.0 

677.0 

21.4 

420.4 
109.8 
48.1 
151 8 
127.5 

3.0 

194 6 

52.8 


31.5 
324.8 
106.4 

22.8 
298.2 

69.5 
184.3 
270.7 
120.0 

52.5 

428.1 
19.3 

323.7 
34.3 
16.4 

47.4 
156.6 

36.3 
213.9 
590.6 

63.6 

22.9 

2.0 

626.2 
34.8 

391.1 
106.4 
46.2 
183.7 
204.7 

3.0 

175.6 
73.3 




1 1 


Belleville 




20 8 


Bowmanville 




9 1 


Brighton 






Brockville 




10 1 


Campbellford 




2 2 


Chesterville 


1.9 




Cobourg 


27 8 


Colborne 




25 8 


Fenelon Falls 




5 3 


Iroquois 


16 9 




Kemptville 


1 2 


Kingston 




27.5 


Lakefield 




1 6 


Lindsay 




6 4 


Mart in town 


6.0 






6 


Millbrook 




2.0 


Napanee 




36.7 


Nepean 


33.7 

9.0 

5.0 

1.0 

50.8 




Newcastle 








Omemee 




Oshawa 




Perth 


13.4 


Peterborough 


29.3 
3.4 
1.9 








Stirling 






31.9 


Trenton 




77.2 


Warkworth 






Wellington 


19.0 




Williamsburg 


20.5 







THUNDER BAY SYSTEM 



The load on the Thunder Bay System during the past fiscal year has shown 
a slight increase over that of the previous year. A large amount of power has 
been sold for the generation of steam electrically with the result that the average 
monthly energy generated showed an increase of 16.1 per cent and the average 
monthly peak an increase of 11.8 per cent over 1932. Excluding this steam 
load, the average monthly energy generated was 5.9 per cent greater and the 
average monthly peak 1.8 per cent higher in 1933 than in 1932. 

The Nipigon Corporation Pulp Mill at Nipigon has not been operating 
during the year, but the station has been maintained alive, Nipigon township 
being supplied from this point. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



49 



HORSEPOWER 



JAN 
FEB 
MAR 
APR 
MAY 
JUNE 

AUG 
SEPT 
OCT 
NOV 
DEC 

FEB 

MAR 
APR 
MAY 
JUNE 

AUG 
SEPT 
OCT 

NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 

SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 

JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
OEC 


'^■ UUU ' M | II II | M 1 II 1 1 1 I 1 1 II II M II 


THUNDER BAY SYSTEM 


PEAK LOADS 


HYDRO-ELECTRIC POWER COMMISSION 




1Z!j,UU0 "~ " — -,,-.-. ^.- . . . ._ _|_ 


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4-4*ttT ^**-«--^r 1 ] 1 r 1923 

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lyzi iyzz 

Mill Mill Mill 


7.771 

FLS 

Mir, 

MAi 
JUNE 
JULY 
AUO 

■>LPT 
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NOV 

DE< 

JAN 

FEB 

APR 
MAY 

JUNE 

JULY 
ALII, 

OCT 
NOV 

DEC 
J AN 
FEB 
MAR 
APR 

MAY 

JUNE 

AUQ 

SEPT 
OCT 

NOV 
OEC 

JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 

AUO 

SEPT 
OCT 
NOV 
D£( 

FEB 

MAR 
APR 

JUNE 
JULY 
ALU, 
SEPT 
OCT 
NOV 
DEI. 



HORSEPOWER 



150,000 



125,000 



100,000 



75,000 



50.000 



25.000 



Two new loads have been added to the system during the year. A bank 
of three 400 kv-a. transformers was placed in service at Cameron Falls generating 
station in September, supplying power to Northern Empire Mines at Empire, 
Ontario, over its 33, 000-volt transmission line. On October 2, two 8,000-kw. 
electric steam-generators and auxiliary equipment at the Great Lakes Paper 
Company were placed in service. Power is supplied to this steam station over 
a short section of 110, 000-volt line, which is tapped off the line to the main 
substation of this company. 






Hydraulic maintenance work has been carried on at Cameron Falls generating 
station during the year, the major items being the repairing of the eroded areas 
of No. 3 and No. 6 turbines by welding the runners. As in former years, special 
attention has been given to the testing and adjustment of governors. During 
September a rather extensive programme of repairs to retaining walls and other 
concrete structures was begun. This work, however, is only about 20 per cent 
complete at the year end. The auxiliary hydraulic equipment has been maintained 
in first class condition. 



50 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

No major maintenance work has been carried out on any of the generators 
at Cameron Falls generating station during the year. All power transformers 
at this station have operated satisfactorily, routine maintenance work only 
being required. The spare transformer, however, was completely overhauled. 

Alexander generating station has given very satisfactory operating service, 
no major maintenance work being required on any equipment throughout the 
year. This station is supervisory controlled from Cameron Falls generating 
station. A few troubles have been experienced with this control equipment, but 
on the whole it has operated satisfactorily. The automatic synchronizer, which 
is used in connection with this supervisory control, has given excellent service 
throughout the year. 

The service obtained from the transmission lines during the year has been 
very good. There have been no total system interruptions, although Port Arthur 
Fort William, Great Lakes Paper Co., and Thunder Bay Paper Co., were inter- 
rupted for 2J/2 minutes on one occasion when No. 2 and 3 lines tripped out at 
both ends and No. 1 line tripped out at Port Arthur during an electrical storm, 
leaving No. 1 line alive to feed Nipigon Corporation. In addition to this, Great 
Lakes Paper Co. suffered four interruptions of short duration, two due to 
accidental operation of oil-breaker 2P1G during wiring alterations for new relays 
at Port Arthur transformer station, and two due to flashovers during electrical 
storms. Fort William experienced one two-minute interruption when a bird 
caused a transmission line flashover. Flashovers during electrical storms were 
responsible for two interruptions, one of 21 minutes and the other of 7 minutes 
duration, to Nipigon Corporation station. The service to Northern Empire 
Mines was interrupted on two occasions due to trees falling across the line. 

Special attention has been given to testing the line insulators and replacing 
those found faulty. Also, the line conductors were closely inspected for broken 
or loose strands and these were repaired where necessary. Some other mainten- 
ance work has been done on the wood-pole lines in tightening guys, etc. Brush 
was cut along certain sections of the right-of way. 

The Port Arthur transformer station has had no curtailment of service to 
any customers due to failures of equipment. New relay equipment was placed 
in service on all 110,000-volt lines, both incoming and outgoing, at this station. 
While sufficient time has not yet elapsed to make a definite statement regarding 
the improvement to service, the time of operation of the breaker equipment 
has been materially reduced, resulting in faster clearances of faults and hence 
less disturbance to the system. Routine inspection and maintenance of the 
110,000-volt oil-breakers and transformers has been carried on throughout the 
year. Connections to the three 110,000-volt lines were altered so that two or 
three lines could be fed through one oil-breaker, thus enabling the other oil- 
breakers to be taken out of service for maintenance purposes. 

The Fort William transformer station has had no failure of equipment or 
incorrect functioning of relays or breakers. Routine maintenance work only 
was required at this station. 

The precipitation in the watershed supplying this system has been relatively 
heavy during the year, approximately 28 inches being recorded. With the light 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



51 



GREAT LAKES 

PAPER CO. LTD. 

(FORT WILLIAM) 



(— I 



■FORT WILLIAM FORT WILLIAM 
'"-^ 22,000 V. f- 1 



tP" 



I/O.000 V. 



//0,000 V. 



THUNDER BAVr-i //0, OOQV . 

PAPER CO. L.J 

PORT ARTHUR 



\m™™ « „ OmO0OV 



NORTHERN 

EMPIRE 

M/HESCO.ITO. 

< 1 

Q 

il 

CAMERON FALLS \n 



_ 22,000 V. 



111 



22,000 V. 



%*?m r^V?™ 



68,200 

HORSEPOWER 



ALEXANDER 



5/, 300 
HORSEPOWER 



PORT ARTHUR 
2,300 V . 



PORT RRTHU/f **D- 0>MT) /yiPIOON 

pumping station corporation l to. 



PORT ARTHUR R.PD. rPART) 



LEGEND 

GENERATING STATIONS 
("HORSEPOWER' IS RATED ELECTRICAL 
HORSEPOWER. AT RATED POWER FACTOR) 

TRANSFORMER STATIONS 



] DISTRIBUTING STATIONS 

O 



THUNDER BAY SYSTEM 

(60 CYCLES) 

DIAGRAM OF STATIONS 

AS AT OCTOBER 31. 1933 



MUNICIPAL STATIONS 
STATIONS & LINES IN SERVICE 



STATIONS & LINES NOT COMMISSIONS PROPERTY. 



HYORO'ELECTRIC POWER COMMISSION 
OF ONTARIO 



load on the system and the heavy precipitation it was found necessary to waste 
a considerable amount of water at both plants during the greater part of the 
year. Notwithstanding the high river flow, the level of lake Nipigon has been 
raised about 6 inches during the year. 

THUNDER BAY SYSTEM— LOADS OF MUNICIPALITIES, 1931-1932-1933 



Municipality 


Peak load in horsepower 


Change 
1932 


in load 
■1933 




Oct. 1931 


Oct. 1932 


Oct. 1933 


Decrease 


Increase 


Fort William 


11,451.7 

70.3 

27,024.4 


10,916.7 

83.0 

35,195.1 


10,932.0 

101.1 

33,205.5 




15.3 


Nipigon Township 

Port Arthur 


' 1,989.6 


18.1 







THUNDER BAY SYSTEM— LOADS OF RURAL POWER DISTRICTS 



Rural power district 



Peak load in horsepower 



Oct. 1931 



Oct. 1932 



Oct. 1933 



Change in load 
1932-1933 



Increase 



Fort William 




35.0 
23.7 


80.0 
33.2 




45.0 


Port Arthur 






9.5 













52 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



HORSEPOWER 



HORSEPOWER 



cnnn < g 1 a 1 I * g a 8 g a I g I a I % i 1 1 8 i a I g I %l 1 1 1 y | a I g I j 1 1 g j g 8 i 1 1 B jj 1 1 g g as i s ., 

5,000 i j | | I I | I I | i i i i i i i i i ] i i i i i i i i i i i i ' i i i i i i i i i i i i i i i i I I I I I j.UUu 



4.000 



3.000 



2.000 



1,000 




S3S33=38S2S 



NORTHERN ONTARIO PROPERTIES 
NIPISSING DISTRICT 

P EAK LOAD S 

HYDRO-ELECTRIC POWER COMMISSION 
OF ONTARIO 



§ 3 S 3 o o BIS S S S S § a S a 5 o Bl< S S E S § a = a « o u 



iSliliiiigii 



4,000 



3,000 



2,000 



1,000 



NORTHERN ONTARIO PROPERTIES 
Nipissing District 



Although the generated peak and average loads on the Nipissing district 
show slight increases for some months over the corresponding months of the 
previous year, a small decrease in load is shown when the records for the entire 
year are compared with those of the previous year. 

The greater storage facilities provided during recent years permitted the 
retention in storage of more water during the spring flood period than in previous 
years, with the result that river flow has been satisfactorily maintained despite 
an unusually dry summer. 

The chief item in the line maintenance programme for the year was the 
replacement of all defective poles, crossarms, insulators and insulator pins on 
the Callander to North Bay, Bingham Chute junction to Callander, and Elliott 
Chute junction to Bingham chute junction sections. All line crossings over rail- 
ways or foreign wires which were found to be substandard, were brought up 
to the standards required by the Board of Railway Commissioners. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



53 



HOW FY GOLD MINES LTD. 



PATRICIA DISTRICT 





ABITIBI CANYON 






55,000 
HORSEPOWER 


EAR FALLS 




/HTERHATIONAL NICKEL CO. 
AT COPPER CLIFF 






5,400 
HORSEPOWER 




.i l 

no. ooov. 




1 j 







ABITIBI DISTRICT'S cycles) 



n 



■OJ 



TREAD WELL 
YUKON MINES 



3. 



5.IOO 

\ horsepower 



Z 2.000 V. 
(N0.2)MCVITTIE 



BUR WASH ^, 
FARM 2,300 V. 



E, 680 
HORSEPOWER 



2 2.000 V. 



(NOJ)CONISTON 



FAL CON BRIDGE 
NICKEL CO. 



5,360 
HORSEPOWER 



(HO. 3) STINSON 



SUDBURY DISTRICT 



MANITOULIN R.P.O.. 
II 



~| HAGA WONG 



r 



i i 

LITTLE RAPIDS PULP COMPANY 



MANITOULIN DISTRICT 



L 



HORTH BAY R.PD. 



ABIT/BI POWER <J PAPER CO. 
STURGEON FALLS 



HORTH BAY I I 

NO. 2 LJ 

2 2, OOOV. 



□ NORTH L 
NO. I 



7} 



CALLANDER I I 
(CANADIAN TIMBER CO. LTD} I 



2.750 

HORSEPOWER 



BIHGHAM CHUTE 



/.200 
HORSEPOWER 



ELLIOTT CHUTE 



1,930 
HORSEPOWER 



-o 



I-*- POWASSAN 1 
POWASSAN RPD ' 



NIPISSING DISTRICT 



LEGEND 

GENERATING STATIONS 
(HORSEPOWER" IS RATED ELECTRICAL 
HORSEPOWER AT RATED POWER FACTOR) 



~J DI5TRIBUT/HG 5TATIOHS 
O MUNICIPAL STATIONS 



— STATIONS £ LINES IN SERV/CE 
_ STATIONS « LINES NOT 
COMMISSION'S PROPERTY 



NORTHERN ONTARIO PROPERTIES 

(60 CYCLES) — (25 CYCLES) 

DIAGRAM OF STATIONS 



AS AT OCTOBER 31. 1933 



HYDRO-ELECTRIC POWER COMMISSION 
OF ONTARIO 



54 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

At Nipissing generating station, new Niagara bronze runners were installed 
in each of the two turbines to replace the cast iron runners which had eroded 
to an extent that made economical repairs impossible. Minor repairs and adjust- 
ments to both turbines were also undertaken. Considerable painting was done 
on buildings and equipment as a protective measure. The design of the pistons 
in the governor oil pumps was changed to eliminate the oil leakage permitted 
by the old design. 

A number of leaks in the wood-stave pipe line were stopped by covering 
each leak with a layer of tarred felt held in place by a steel plate pre-formed 
to the curvature of the pipe and inserted under the pipe bands. Several of the 
pipe line supporting saddles were also renewed. 

At Bingham Chute generating station, very little maintenance work was 
found necessary on the turbines. Renewal of gate link pins on No. 2 unit, 
renewal of lignum vitae bearings and adjustment of journal bearings on both 
units were undertaken. One 300-kw. power transformer at this station failed 
in service due to development of a leak in the bronze cooling coils. Repairs 
were made to the winding, the defective coils were replaced with new copper 
coils, and the old oil, which was known to be slightly high in acid content, was 
replaced with new oil. Renewal of coils and oil in the remaining two transformers 
in the three-phase bank is being undertaken to safeguard against similar failures 
in these units. The choke coils were removed from the 22,000-volt structure. 
Earth resistances were measured and station grounding improved. 

The chief operator's cottage at this station was completely redecorated. 

At Elliott Chute generating station, only routine turbine maintenance work 
was required. A new spring type flexible drive for the generator overspeed 
device was installed to replace the original drive which has failed on several 
occasions. 

A woven wire fence was erected along the roadway on the southern boundary 
of the property. 

The decayed plank facing of the rock-filled woodcrib breakwater at this 
station was renewed with 1-inch plank and covered with one-eighth-inch steel 
plates from salvage. The frame store-house was raised and placed on concrete 
posts. The west end of the earth fill dam was surfaced with 30 yards of gravel. 

At the Canadian Timber Company substation in Callander, one high-tension 
transformer bushing failed in service and was replaced with a new bushing. 

Megger tests on practically all electrical equipment were made throughout 
the year, initiating a programme of periodical megger tests to obtain indications 
of insulation deterioration by comparison of results of tests taken at intervals 
over a period of time. The programme of progressive grading of insulators, 
instituted last year, was continued through the current year. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



55 



20,000 



10,000 



FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

DEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

DEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

DEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 


T 










i o^n 1 qiq - 


(you iyo«3 
1931 


'V -> f*y '^ w " icn? /^ 


* lA -, r J 


::::::::::„:_^:"/::^,::::::::"::::t::::::::::::::::i 


____L---_w-- y ---,J 


XJ— 


*j j 


m 


NORTHERN ONTARIO PROPERTIES 


SUDBURY DISTRICT 


DC" A V 1 HA nC 


rtAr\ LUAUo 


HYDRO -ELECTRIC POWER COMMISSION 


1 1 1 1 1 1 II 1 1 1 1 1 1 1 1 1 1 II II ! 1 II 1 I 1 1 II II 1 


jam 
FEB 

APR 

JUNE 

JULY 

AUG 

SEPT 
OCT 
NOV 
DEC 

FEB 

MAR 
APR 
MAY 

JUNE 

AUG 

SEPT 
OCT 

MOV 

DEC 

JAM 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 
JAM 
FFB 
MAR 
APR 

JUNE 
JULY 

AUG 

SEPT 
OCT 

NOV 

DEC 

JAM 
FEB 

MAR 
APR 

MAY 
JUNE 

AUG 
SEPT 
OCT 

NOV 

DEI 



20,000 



10,000 



Sudbury District 

The generated peak and average loads on the Sudbury district showed a 
marked decrease for the first six months of the current fiscal year as compared 
to corresponding months of the previous year. Owing to improved conditions 
in the nickel industry, however, a decided upward trend, which started in May, 
1933, has continued throughout the remainder of the year. The extent of this 
improvement is illustrated by the fact that in October, 1933, the generated 
peak load showed an increase of 65 per cent and the generated average load an 
increase of 91 per cent over the corresponding month of 1932. 

The level of Wahnapitae lake was lowered approximately four feet below 
the normal operating level during the summer months to accommodate certain 
mining properties bordering on the lake. This action together with the 
subnormal precipitation of the past summer demanded more than usual care in 
the regulation of river flow and division of load between generating stations in 
order to obtain the maximum efficiency in the use of storage water. 

Line maintenance work in the district was confined to insulator testing, 
replacement of defective insulators, butt treatment of poles where necessary and 
similar details of a routine nature. 



At Coniston generating station, No. 2 turbine was completely overhauled. 
This work included the installation of alemite fittings to facilitate greasing of 
bearing surfaces between gates and gate bolts and between speed rings and 
operating rings. A new gear quadrant was installed on the gate operating 
mechanism. New gate links, link pins, and link bushings were supplied where 
required. 



56 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Four new timber head-gates were constructed and installed to replace the 
head-gates which had become unsafe through deterioration of the timbers. 

The generating station air compressor was moved to a new and more con- 
venient situation. Repairs were made to the roofs of the store-house, generating 
station, transformer house and penstock house. The generating station floor, 
boarding-house interior woodwork and store-house and transformer house trim 
were painted. 

The road between the generating station and the highway was widened 
and surfaced with gravel. 

To improve frequency regulation and time service a synchronome, having 
a synchronous motor driven clock and an accurate mechanical clock movement 
with dials to indicate the variation between times as computed by the two 
types, was installed at Coniston generating station. A radio receiving set for 
the reception of time signals was also installed to permit accurate setting of the 
mechanically operated movement. With the synchronome indication as a guide 
the staff has been able to regulate system frequency much more closely than 
heretofore. 

At McVittie generating station, the armature of No. 1 generator failed in 
service on four occasions and the armature of No. 2 generator failed once during 
the year. Failures in all cases were due to lightning surges which are assumed 
to have entered the station on a 2,200-volt feeder. These generators have been 
in service for more than twenty years and the repeated failures were attributed 
largely to deterioration of the windings with age. A complete new winding has 
been installed in No. 1 generator to eliminate further costly failures. 

Mechanical maintenance work at this station was confined to small items 
such as the renewal of the lignum vitae bearing and the replacement of a defective 
thrust nut on the exciter turbine, governor adjustments, and repairs to two 
bearing pedestals in which cracks had developed. A set of disconnecting switches 
was installed to permit isolation of the high-tension arresters. Station grounding 
was improved and tested. Extensive painting inside the generating station was 
undertaken. 

At Stinson generating station, the two 3,500-horsepower turbines were 
completely overhauled. Each unit was equipped with alemite fittings to facilitate 
greasing the bearing surfaces between gates and gate bolts and between speed 
rings and operating rings. A brake was installed on each unit whereby the unit 
can be quickly stopped by application of pressure to the periphery of the flywheel. 

Following the failure of one of the timber head-gates at this station, two 
new head-gates of heavier design were installed to replace the originals. A pipe 
railing was erected on the lower side of the path between generating station 
and head block as a safety measure. 

The exterior walls of the penstock building were painted and one coat of 
roofing paint was applied to the roof. Rust was removed from the penstocks 
and the cleaned surface painted, where required. Considerable painting was 
undertaken inside the station. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



57 



HORSEPOWER 



HORSEPOWER 



60,000 



> 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

DEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

DEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

DEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

DEC 

FEB 

MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 












A 




1 




' 






- 1Q^^ - 


i yoj 














- 1 QOI _ 1 QOO 


lyoi lyjz 

1 4 


4X— JL ..--/--- — 


k. j \„ -e' J ^ 


• nnwi — - — - _- MADTUTDM r\MTADir\ DDADCDTirC - 


10,000- - -- -- -- inUKIHLKIN UlNIAKIU rKUrLKIItb 


ABITIB1 DISTRICT 


PEAK LOADS 




HYDRO-ELECTRIC POWER COMMISSION 


OF ONTARIO 


r. 

JAN 
FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

DEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

DEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

OEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

DEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

DEC 



50,000 



40.000 



30.000 



20,000 



10,000 



Abitibi District 

On the Abitibi district the peak and average loads for the first eight months 
of the fiscal year were, in general, slightly higher than for the corresponding 
months of the previous year. Improved conditions in the nickel industry were 
responsible for a decided load increase during the next three months, and during 
the final month of the fiscal year the load was greatly increased by the addition 
of the Abitibi Power and Paper Company's steam-generation load at Iroquois 
Falls. 



Until the No. 1 unit at Abitibi Canyon generating station was first placed 
in service, power was purchased from the Abitibi Electric Development Com- 
pany's generating station at Island Falls for transmission to Copper Cliff to 
serve the International Nickel Company at that point. This power was trans- 
mitted from Island Falls to Hunta, 14 miles west of Cochrane, over the Abitibi 
Electric Development Company's circuit and from Hunta to Copper Cliff, a 
distance of 189 miles, over the Commission's double-circuit steel-tower line. 



58 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

On May 24, the Copper Cliff load was transferred from Island Falls generating 
station to the Abitibi Canyon generating station, thus marking the initial 
delivery of commercial power from the latter station. A double-circuit steel- 
tower line from Abitibi Canyon generating station is connected at Hunta to 
the aforementioned double-circuit steel-tower line from Hunta to Copper Cliff, 
making a total transmission distance from Abitibi Canyon to Copper Cliff of 246 
miles. A single circuit only is used to supply Copper Cliff at the present time 
but the second circuit is kept available for service as a standby. 

On October 23, the initial delivery of power was made to the Iroquois 
Falls mill of the Abitibi Power and Paper Company, for purposes of steam 
generation. This power is transmitted over the Commission's lines from Abitibi 
Canyon to Hunta where connection is made with the Abitibi Electric Develop- 
ment Company's line to Iroquois Falls. 

Service interruptions due to electrical storms have been more frequent on 
this district than would be anticipated from the records of other districts operated 
by the Commission. This has been attributed to the apparent higher storm 
frequency in the area served, coupled with the fact that the 246 miles of trans- 
mission line from Abitibi Canyon to Copper Cliff runs almost due south, thus 
intercepting a greater number of storms (which usually travel east and west) 
than the Commission's other lines of similar length which run in an east and 
west direction. 

Maintenance of lines on the district was confined chiefly to replacement of 
a small number of insulators, most of which showed evidences of being damaged 
by rifle shots. Considerable brush cutting was found necessary on the right-of-way 
of the Hunta to Copper Cliff section of line. A close inspection of lines for loose 
tower bolts, deterioration of absorber rods, power conductor and ground con- 
ductor at points of suspension was made in both the spring and fall seasons. 

The operation of the Abitibi Canyon generating station has been satisfactory 
during the few months it has been in service. Various adjustments and changes 
have been necessary, as is usually the case when a new station is placed in service, 
but these have been of a minor nature. 

Toward the latter part of August the second generator at Abitibi Canyon 
generating station was sufficiently advanced to be placed in service. This released 
No. 1 generator for various adjustments. From this time to the end of the fiscal 
year, although two generators were at times available, the necessity of removing 
one or the other from service for adjustment, limited the capacity available for 
commercially continuous service to that of one unit. 

Patricia District 

The generating and transformer station at Ear Falls on the English river 
has been in satisfactory operation throughout the year. All equipment has 
functioned as required, there being no failures of major importance. The load 
on the system has shown an increase over that existing during the previous year. 
The average monthly energy generated was about 2.8 per cent greater and the 
average monthly peak approximately 8.9 per cent higher during 1933 than 
in 1932. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



59 



HORSEPOWER 



HORSEPOWER 



3.000 



3 

3 
JAN 
FEB 

APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 

FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

DEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

DEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT 

NOV 

DEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

AUG 
SEPT 
OCT 
NOV 
DEC 


J,uuu Mill 

IQOQ 


iyjo 


f 

1QQ9 J 


i yo^i j 

1 QOI 1 ' j 


lyoi ^^-^ 7 


Z.UUU f ' ^^?3 • ' V '" ~1~ 

1QOf| ~S 


i yju *-> 


/*"**"*" 


/r / 


/ NORTHERN ONTARIO PROPERTIES 


J PATRICIA DISTRICT 




* " PEAK LOADS 


HYDRO-ELECTRIC POWER COMMISSION 


OF ONTARIO 


c 

JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 

AUG 
SEPT 
OCT 
NOV 
DEC 

FEB 

MAR 
APR 
MAY 
JUNE 

AUG 
SEPT 
OCT 
NOV 
DEC 

FEB 

MAR 
APR 

JUNE 
JULY 

SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 

APR 

JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 



2,000 



- 1,000 



Four interruptions to service took place during the year, one of which was 
of rather long duration. On November 16, 1932, oil breaker IB IT opened 
automatically due to trouble on the 44,000-volt transmission line. The trouble 
was found to be due to failure of a crossarm through-bolt which permitted the 
arm to swing down against the telephone crossarm, breaking one insulator. 
Due to communication being cut off from the Howey Mines and travelling in 
the deep snow being very slow, service was not resumed until 31 hours and 6 
minutes later. On June 29 a 2-minute interruption to service occurred due to 
a flashover on the 44,000-volt transmission line during a lightning storm. On 
July 24 service was interrupted for one minute when oil-breaker IB IT opened 
automatically in conjunction with oil-breaker 151 on the feeder to the water 
rheostat, due to a flashover on this feeder during a lightning storm. On August 
16 a flashover occurred on one of the 2,200-volt feeders at Howey Mines during 
a lightning storm, 1B1T oil-breaker opened automatically and the operator had 
some difficulty in restoring normal voltage to the generator, with the result 
that an interruption of 19 minutes resulted. 

A certain amount of maintenance work has been carried out on the major 
equipment during pre-arranged plant shut-downs. On July 7 the turbine was 
unwatered and the turbine and various hydraulic features were inspected and 
found to be in good condition. The turbine-operating mechanism, governor 
system and auxiliary mechanical equipment have been inspected and overhauled 
where needed. 

The 44,000-volt transmission line between the generating station and the 
Howey gold mine, which is owned by the Howey Gold Mines Limited, has been 
operated and maintained for this Company throughout the year under the same 
arrangement for costs as previously. This transmission circuit has functioned 
very satisfactorily during the year, although it was responsible for the two 
outages outlined above. 

The flow in the English river has been adjusted from time to time, as required 
by the Lake-of-the-Woods Control Board, by means of the regulating dam at 
Ear Falls. 



60 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



The precipitation in the vicinity of Ear Falls has been about normal, being 
25 inches during the year. With this precipitation, as well as conservation of 
water when not required, the level of Lac Seul has been raised about one foot 
during the year, the elevation on October 31, 1933, being 1160.8 as against 
1159.9 on the corresponding day last year. 

Manitoulin District 

The Manitoulin district was first served by the Commission on December 
16, 1932. Power purchased and metered by the Commission at the 600-volt 
bus of the Manitoulin Pulp Company's mill at Kagawong is stepped up to 
12,000 volts between phases by means of three 100-kv-a. transformers which 
are installed in an outdoor-type station close to the mill. From this station 
power is supplied to the Manitoulin rural power district which at present consists 
of the municipalities of Gore Bay, Mindemoya and Kagawong, and a number 
of rural customers. Service has been satisfactorily maintained throughout the 
year. 

NORTHERN ONTARIO PROPERTIES— LOADS OF MUNICIPALITIES, 1931-1932-1933 



Municipality 



Peak load in horsepower 



Oct. 1931 Oct. 1932 Oct. 1933 



Change in load 
1932-1933 



Decrease Increase 



NIPISSING DISTRICT 



Callander. . 
Nipissing. . . 
North Bay 
Powassan . . 



112 


8 


3 





2,921 


8 


117 


7 



175 





3 





,915 





131 






196 


4 


3 





,911 


4 


106 


5 



3.6 
24.5 



21.4 



SUDBURY DISTRICT 


Sudbury 


3,967.8 


3,667.5 


3,599 2 


68.3 








NORTHERN ONTARIO PROPERTIES— LOADS OF RURAL POWER DISTRICTS, 

1931-1932-1933 



Rural power district 



Peak load in horsepower 



Oct. 1931 Oct. 1932 Oct. 1933 



Change in load 
1932-1933 



NIPISSING DISTRICT 


North Bay 


68.3 


77.0 
2.0 


77.9 
3.0 


9 


Powassan . 




,0 








MANITOULIN DISTRICT 


Manitoulin ... 


Date connected 
Dec. 16/32 


Initial load 
70.0 


79.9 




9 9 



















1934 HYDRO-ELECTRIC POWER COMMISSION 61 



SECTION III 



MUNICIPAL WORK 



The Commission acts in an advisory capacity in connection with the 
operation of the "Hydro" utilities of the various municipalities with which it 
has contracts. In this connection the Commission arranges for the purchase, 
construction or extension of distribution systems and assists the municipal 
officials in making their financial arrangements to pay for the cost of these 
systems. All rate adjustments, as provided under The Power Commission Act, 
are recommended by the Commission, and a study of the operating conditions 
of all utilities is made annually and adjustments recommended accordingly. 
The Commission exercises a general supervision over the management and 
operation of all systems more especially in the smaller municipalities which, 
individually, are not of sufficient size to employ a manager with the technical 
knowledge necessary to administer properly all phases of the local system's 
operation. 

In the case of the rural power districts, the Commission itself — on behalf 
of the corporations of the individual townships — operates the rural power 
systems, and distributes electrical energy to the customers of the respective 
corporations in any such rural power district. 



NIAGARA SYSTEM 

During the month of July, 1933, the Commission commenced taking power 
from the McLaren-Quebec Power Company. This power was transmitted over 
the 220,000-volt line from Beaudet to Chats Falls generating station by which 
power is obtained from the Beauharnois Light, Heat and Power Company. 
Commencing with the month of October, an additional block of power was 
taken from the Beauharnois Light, Heat and Power Company also over this 
line. 

The load conditions on the Niagara system during the fiscal year, 1933, 
show an increase in the total amount of power taken by municipalities and 
industrial companies during the months of November and December, 1932, 
February, April, July, August, September and October, 1933, as compared 



62 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

with the corresponding months of the previous year. During the months of 
January, March, May and June, a slight decrease is shown in the amount of 
power taken, as compared with the previous year. These figures, however, do 
not include secondary power sold for process steam generation, and for export 
to the United States. Commencing with the month of February, the Com- 
mission sold a substantial block of secondary power to the pulp and paper 
industry for the generation of process steam, and in the month of June, resumed 
the sale of additional secondary power to the Canadian Niagara Power Company 
for export. The loads on the systems of the Commission are referred to more 
fully in Section II of this report. 



Dominion Power and Transmission Properties 

The distribution systems of the Dominion Power and Transmission Company 
in the cities of Hamilton and Brantford which were sold during 1931 and 1932 
respectively have proved to be entirely satisfactory. The arrangements of sale 
provided for the purchase of these properties by payments extending over a 
number of years, but it is expected that the entire purchase price of the systems 
in both these cities will be paid sooner than originally planned. 

Negotiations are under way in connection with the sale of the Dominion 
Power and Transmission Company's distribution system in St. Catharines to 
the local commission. The rural distributing lines of this Company have already 
been absorbed in the several rural power districts in which they are situated. 



"Secondary" Power 

"Secondary" power is a term applied to power which is sold subject to 
unlimited interruptions, to reduction or to complete withdrawal, at any time 
it is required for use by municipalities, or for the maintenance of the supply 
of firm power. Although the Niagara system of the Commission has a high 
load-factor it has, of course, daily and seasonal peaks; thus there are, even in 
times of normal industrial activity, periods of the day and of the year when 
large amounts of "secondary" power are available. "Secondary" power, how- 
ever, on account of the uncertainty of the times and durations of the system 
peaks, is not sufficiently dependable for ordinary industrial uses. A limited 
amount of such power can be utilized by large special industries in certain 
heating and electro-chemical processes. Although Canadian consumers are at 
all times given priority of consideration, the chief market for "secondary" 
power which the Commission has had at its disposal on the Niagara system has 
up till recently been in adjacent territory in the United States served by supply 
systems securing a large proportion of their power from steam plants. Such 
systems, by utilizing, when available, this "secondary" power can conserve their 
fuel supplies. The sale of this power to the Canadian Niagara Power Company 
for use in the United States has enabled the Commission to employ profitably 
its generating equipment at times when not required to take care of the demands 
of the Niagara system. During the latter part of the year this Company has 
resumed taking this kind of power in substantial quantities. 



1934 HYDRO-ELECTRIC POWER COMMISSION 63 

Profitable Employment of System Reserve Generating Capacity 

In times of curtailed industrial activity the amount of reserve power capacity 
which it is necessary to maintain, increases. If this reserve capacity can be 
put to profitable temporary use under conditions or contracts that ensure the 
maintenance of its character as system reserves, it is an economic gain to the 
Province and brings to the Hydro undertaking a revenue which reduces the cost 
of maintaining the essential reserves. 

One market for this type of power is found in the production of steam for 
industrial processes. During the past year the Commission has supplied sub- 
stantial amounts of secondary power for steam purposes and arrangements are 
being made to supply other companies in a similar manner. As general economic 
conditions improve, there will be less reserve power available for this purpose 
because more will be required for the normal uses of the municipalities. Mean- 
time, it may be noted, the utilization of reserve power for the production of 
process steam replaces imported coal. 



Engineering Assistance to Municipalities 

General engineering assistance was given during the year to practically all 
of the municipalities in the Niagara system, by a general supervision of 
management and operation. 

Estimates and work in connection with the rebuilding of distribution systems 
to take care of various conditions was undertaken during the year and additional 
transformer capacity provided where necessary in the following places : Amherst- 
burg, Aylmer, Beachville, Blenheim, Brampton, Caledonia, Dresden, Drumbo, 
Dundas, Exeter, Fergus, Fonthill, Goderich, Mimico, New Hamburg, Niagara- 
on-the-Lake, North YorkTwp., Otterville, Paris, Plattsville, Port Credit, Preston, 
Ridgetown, St. Jacobs, Seaforth, Simcoe, Strathroy, Tilbury, Toronto Twp., 
Waterdown, Wellesley, Weston and Woodbridge. 

Certain municipalities received special engineering advice and assistance 
regarding a number of matters, which are more fully referred to as follows: 

Chatham — A 200-horsepower fire pump is being installed. The motor will 
operate at 4,000 volts and the pump will have a capacity of 5,000,000 imperial 
gallons per 24 hours at a pressure of 110 pounds. The present steam pump 
stand-by will be replaced with two gasoline-engine driven pumps in order to 
reduce the waterworks operating costs. The distance from the Chatham Hydro 
utility step-down station to the waterworks pumping station is approximately 
one mile and a special feeder will be erected. 

Dunnville — An additional primary circuit and a new transformer bank were 
constructed for service to power consumers who were increasing their loads. 

Georgetown — New lines were designed and their locations determined 
preparatory to removing circuits from the main street. Arrangements were made 
also for additional primary lines to improve service to power customers. 



64 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Goderich — Plans were made for rebuilding of a portion of the distribution 
lines which had become overloaded and particularly with a view to securing a 
primary loop so that interruptions for repair work would be reduced to the 
minimum. 

Humberstone — Provision for convenience of operation and better service 
by arranging for interswitching with Port Colborne, is being undertaken, together 
with general system revision. Plans were submitted by the Commission's 
engineers and the work is being done under their supervision. 

London — A new 13,200-volt feeder consisting of 3-conductor 4/0 cable was 
laid between the Commission's high-tension station and the corner of Highbury 
avenue and King street to take care of the increasing industrial load in this area. 

St. Marys — The severe wind storm on June 9, badly damaged the circuits in 
all parts of St. Marys. Advantage was taken of the situation when rebuilding to 
replace equipment which had become inadequate, particularly conductor, and a 
large portion of the distribution system was rebuilt with larger conductor, new 
poles and heavier line material. 

Sarnia — Specifications were prepared for the installation of two electrically 
driven domestic water pumps in the waterworks plant. These pumps will be 
equipped with 4, 000- volt motors and have a capacity of 150 and 200 horsepower 
respectively. The present steam-driven pump will be retained as a stand-by in 
case of fire. Power will be supplied over a separate feeder from No. 1 municipal 
station to the pumping plant, a distance of approximately one and a half miles. 
The pumps will be capable of delivering 3,240,000 imperial gallons and 4,320,000 
imperial gallons of water per 24 hours. 

Tillsonburg — Plans are being prepared for the complete overhauling of 
the local substation, partly due to increased load and partly to obtain better 
operating conditions. 



GEORGIAN BAY SYSTEM 

A small increase occurred in the power demand of this system during the 
year, but for the most part, the loads in the various municipalities were constant 
with respect to previous year conditions. A new industry of fair magnitude in 
one of the municipalities, together with a large number of new consumers taken 
on in the summer resort districts, established a higher system peak during a 
portion of the year, but as the new summer load is in existence for only about 
two or three months, and as the new industrial load was in operation during the 
latter part of the year only, the total yearly average load increase was not greatly 
affected. 

The distribution system in the village of Mildmay purchased last year by 
the Commission from The Mildmay Electric Light Company, was sold to the 
corporation of the village, and the distribution system purchased last year from 



1934 HYDRO-ELECTRIC POWER COMMISSION 65 

The Formosa Electric Light Company was merged into the Bruce Rural Power 
District, and service given to the various consumers in accordance with the rural 
sections of the Power Commission Act. 

A new 22,000-volt transmission line was constructed between Shelburne 
and Orangeville replacing the old line purchased from The Pine River Light & 
Power Company in 1916, and all financial matters, as well as all features of 
improved service in connection therewith, were placed before all the munici- 
palities affected by the change, and approval obtained. Arrangements were also 
made for reconstructing the transmission line between Grand Valley and Arthur, 
and a large portion of this was completed during the year. 

General engineering assistance and advice concerning the maintenance and 
operation of the various local distribution systems, also assistance in connection 
with the application of rates, and the submission of information to power and 
lighting customers was rendered to all of the municipalities throughout the year. 

Engineering advice of a special nature in connection with matters referred 
to was given to the following municipalities: 

Chatsworth — Plans and specifications were prepared covering a complete 
rebuilding of the local distribution system. 

Formosa — The primary line out of the Walkerton generating station which 
feeds the hamlet of Formosa, as well as the local distribution system of Walkerton, 
was completely reconstructed and made a part of the Bruce rural power district. 

Kincardine — The Public Utilities Commission submitted information con- 
cerning the cost of power to a new industry. It negotiated a contract for power 
service, rebuilt a portion of the distribution system in order to deliver power to 
this new consumer, and enlarged the local substation to provide adequate trans- 
former capacity for supplying this new load in conjunction with the existing load 
in the municipality. 

EASTERN ONTARIO SYSTEM 



This system includes the Central Ontario, St. Lawrence, Rideau, Ottawa 
and Madawaska districts. The area served is that part of Ontario lying east of 
the area served by the Georgian Bay and Niagara systems. 

The power supply is from developments owned by the Commission on the 
Trent Canal system and on the Mississippi and Madawaska rivers. Power is 
purchased from the Gatineau Power Company, the Rideau Power Company 
and the Beach Estate at Iroquois. 

The Commission controls or has an interest in a number of undeveloped 
water-power sites on the Ottawa, Mississippi and Madawaska rivers, from which 
sites additional power can be made available when warranted by the demand. 
At present the growth of load is met by increased deliveries of power purchased 
under contract with the Gatineau Power Company. 



66 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Owing to low water conditions on the Trent Canal system, the power allot- 
ments due from the Gatineau Power Company were all required in the closing 
months of this year. 

General engineering assistance and advice was given to municipalities 
concerning the management and operation of the various local distribution 
systems. 

Certain municipalities received special engineering advice and assistance 
regarding a number of matters, which are more fully referred to as follows: 

Bobcaygeon — Estimates on the cost of power were given to this munici- 
pality last year but no action was taken by the municipal officials. This year a 
further request was received from the municipality for new estimates. New 
estimates based on present conditions were submitted. 

Brockvllle — The Brockville Public Utilities Commission has this year paid 
off all its debenture debt against the local utilities. This event was celebrated by 
a banquet on October 12, 1933, at which the members of the Provincial 
Commission were guests of honour. 

Cobourg — The electrical distribution system and waterworks which were 
purchased by the Corporation from the Commission last year, were managed 
and operated by the Commission on behalf of the Corporation from January 1, 
1932, to January 1, 1933, when the management and operation of these utilities 
were taken over by the Cobourg Public Utilities Commission, which will operate 
them, in future, on behalf of the Corporation. 

Colborne — The corporation of Colborne concluded negotiations for the 
purchase of the distribution system in the village from the Peebles Estate on 
January 1 , 1933. From this date the system has been operated by the municipality 
under a cost contract with this Commission. 

Newcastle — An extension of the Newcastle distribution system to New- 
castle-on-the-Lake authorized last year was completed and power made available 
for the summer season. 

Norwood— The rebuilding of part of the local distribution system, neces- 
sitated by improvements to the highway, was completed by the Commission on 
behalf of the municipality. 



THUNDER BAY SYSTEM 

An outstanding improvement has taken place in the demand for power on 
this system during the year. A large portion of the load increase was not obtained 
until near the end of the current year, but early in the new year the entire surplus 
capacity of the two generating plants at Cameron Falls and Alexander will be 
sold and the generating equipment of the combined developments on the Nipigon 
river will be completely loaded for the first time since the completion of the 



1934 HYDRO-ELECTRIC POWER COMMISSION 67 

Alexander development. One of the large pulp and paper mills at Port Arthur, 
formerly closed down, resumed operations during the last four months of the year, 
and another large mill in Fort William increased its demand by several thousand 
horsepower. 

New load to the extent of approximately 40,000 horsepower was contracted 
for, with two large pulp and paper mills for the operation of electric steam 
generators. This new load was sold on an "at-will" basis and is recallable at 
any time during the term of the agreements should the power be required for 
supplying firm power to new or existing consumers. One of these steam generator 
installations, with a demand of about 18,000 horsepower, was placed in operation 
in September, and the installation of equipment under the other contract is nearly 
completed and will probably be placed in operation during the first month of 
the new year. 

A large extension was made to the Port Arthur rural power district and 
service was given to approximately 60 summer consumers situated along the 
shores of Thunder Bay east of Port Arthur. 

Engineering assistance and advice covering the management and operation 
of the various distribution systems was given to the cities of Fort William and 
Port Arthur, and to the village of Nipigon, and the complete operation of the 
Port Arthur and Fort William rural power districts was carried on by the 
Commission on behalf of the various townships concerned. 



NORTHERN ONTARIO PROPERTIES 

Nipissing District 

This district comprises the area lying north and east of Lake Nipissing, and 
is served by three generating plants, situated on the South river, supplying 
electrical energy to the city of North Bay, the town of Powassan, the unincor- 
porated hamlets of Callander and Nipissing and the rural districts adjacent to 
North Bay and Powassan. Load conditions in this district were fairly constant 
throughout the year, in consequence of which no special changes, or improvements 
were required in generating plant, transformation, transmission, or distribution 
equipment. Arrangements were made, however, to secure an additional 750-kv-a 
in transformer capacity for North Bay to provide spare or emergency equipment 
for future operation. 

Abitibi District 

This district comprises the entire area lying within transmission distance of 
the Abitibi Canyon development, including the mining districts adjacent to 
Sudbury, Kirkland Lake, and Timmins. During the year the Commission 
became responsible for the operation of the Abitibi Canyon development and 
transmission lines, formerly the property of The Ontario Power Service Cor- 
poration. The Abitibi Canyon development was placed in operation during the 
month of May, and an engineer was assigned to the Abitibi district in order to 
maintain contact with all of the existing and prospective mining companies, for 
the purpose of submitting information in connection with the use of electrical 



68 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

energy and the cost thereof, and negotiating contracts for the sale of power. 
Definite information was submitted to the officials of several new mining proper- 
ties and details of agreement covering the sale of power were discussed. It is 
expected that several agreements covering the delivery of electrical energy will 
be closed with these mining companies early in the new year. A contract was 
also completed with The Canada Northern Power Corporation covering the sale 
of power by the Commission to the company of its entire future load growth for 
a period of ten years. A large block of "at-will" power was sold to one of the large 
paper companies under a temporary agreement, for electric steam generation, 
and arrangements were made to negotiate a long-term contract with the same 
company for 60,000 horsepower under similar conditions. It is anticipated that 
the results of the efforts being made will require the construction of from 150 to 
200 miles of high-tension transmission line, and of several transformer stations 
early next year, to take care of local growth in this district. 



Sudbury District 

The district comprises the area adjacent to the city of Sudbury, to which 
power is supplied at 60 cycles from three power developments on the Wahnapitae 
river. The demand for 60-cycle power in this district has been such that the 
power that can be produced by the generating capacity of these three develop- 
ments has all been sold, and any further load increase will have to be taken care 
of by 25-cycle power from the Abitibi Canyon development and transmission 
line, or, by the installation of frequency changer sets. A new contract was nego- 
tiated with one of the large mining companies, providing for an increased demand 
of 50 per cent, and assistance was given to the city of Sudbury in connection with 
the operation of its local distribution system. Information was also submitted 
to the rural districts adjacent to Sudbury with respect to procedure concerning 
the securing of Hydro-Electric service from the Commission. 

Patricia District 

Information and advice was given to the large gold mine, at present being 
served from the Ear Falls development. A survey was made, estimates were 
prepared, and negotiations carried on concerning the construction of a develop- 
ment at the foot of Lake Joseph on the Albany river in connection with supplying 
power to two mining properties. 

Manitoulin District 

This district comprises the entire Island of Manitoulin, and, at the present 
time, power is being delivered to a rural power district, inclusive of the town of 
Gore Bay, and the hamlet of Mindemoya. Meetings were held throughout the 
year in the eastern section of the island adjacent to Little Current and Mani- 
towaning, also Sheguindah, in connection with supplying these municipalities, 
and adjacent rural sections, by means of any extension to the existing lines, or 
by securing power from another development. At the present time power is 
being purchased from the Kagawong development of The Little Rapids Pulp 
Company under a contract which was executed during the year. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



69 




RURAL ELECTRICAL SERVICE IN ONTARIO 

A cheese factory utilizing electric power — one of many rural industries that have experienced 

the economy of "Hydro" service 



RURAL ELECTRICAL SERVICE 



There are now 171 operating rural power districts served by the Commission. 
These districts deliver power to approximately 62,000 rural consumers in 352 
townships and 92 police villages, over a network of rural primary lines which, in 
length, aggregates more than 9,000 miles. In addition to the 352 townships 
served, there are 8 townships served jointly by rural power districts and voted 
areas. In the years prior to 1920 this service was supplied to townships and for 
the most part the rural consumers were reached by extensions to existing urban 
and suburban distribution networks. In 1920, amendments to The Power 
Commission Act provided for the formation of rural power districts and in 1921 
and 1924 special rural Acts were passed by the Provincial Legislature providing 
for the payment of Provincial "grants-in-aid." These legislative enactments; 
*the special consideration given to rural electrical service; and the experience 
gained and put into practice by the Commission, have resulted in a remarkable 
growth in rural electrical service in Ontario. This is well shown by the accom- 
panying charts. There is, indeed, no branch of the Commission's activities to 
which, during recent years, more detailed consideration has been given than its 
department of rural electrical service. 

*Re Rural Power District Legislation: — Consult The Power Commission Act (R.S.O. 1927, 
ch. 57): The Rural Hydro-Electric Distribution Act ((R.S.O. 1927, ch. 59; The Rural Power District 
Loans Act, 1930 (20 Geo. V, ch. 14), and The Rural Power District Service Charge Act, 1930 (20 
Geo. V, ch. 15). 



70 



TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 







RURAL ELECTRICAL 



Hydro service brings to Ontario farms a higher standard of 

in house, dairy and barn. Only those city people 

farm under other methods can fully 



Distribution of power to rural communities has now gained an established 
place in Ontario country life. The improvements that can be effected in the 
standard of living by the generous use of electricity on the farm and in the farm 
home are everywhere recognized. It is clean for the house, convenient and safe 
for all uses and under Hydro rates very economical. Even during the past two 
years when the cumulative effects of the period of economic stress have been most 
acutely felt, appreciable gains have been made in rural power districts both to 
the number of consumers served and to the total mileage of lines. 



It must, however, be recognized that rural electrical service is essentially a 
community interest and to attain its greatest success must have the whole- 
hearted support of all rural dwellers. Co-operation is the keynote of success. 
Primarily, rural service is made possible by the great networks of transmission 
lines which have been constructed to serve urban municipalities. These networks 
afford a base from which rural primary lines may economically be extended over 
wide areas of the more closely settled parts of rural Ontario. Thus there is 
co-operation between the urban and rural citizens. The growth in the mileage of 
rural lines during normal years has been phenomenal, until at the present time 
the aggregate length of such lines exceeds the mileage of the main transmission 
lines built to serve urban centres. In the rural power districts the transmission 
lines which serve the individual farmers can also carry electrical energy to 
churches, schools and stores, as well as provide power for factories utilizing 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



71 




SERVICE IN ONTARIO 



living with comfort and relief from many arduous tasks 
who have had experience of life and work on the 
appreciate the benefits of this service 



agricultural products as their raw material. Thus, co-operation produces the 
greatest benefit to all and results in lower costs. 

In supplying electrical service to rural districts the Commission has followed 
a comprehensive and carefully thought-out programme. Rural power districts 
are designed to be economic unit areas with respect to the transmission lines and 
power supply facilities that are available, and their boundaries are not arbitrary 
geographical limits such, for example, as define the areas of townships. In practice 
a typical district covers about 100 square miles. 

The experience gained by the Commission and the improvements in tech- 
nique enable electrical service to be given to rural districts when there can be 
secured three signed farm contracts, or their equivalent, per mile of line to be 
constructed. 

Provincial Government Aids Rural Service 

Assistance respecting electrical service is given by the Province to farmers 
and rural residents in three ways, namely: 

First — A grant-in-aid toward the initial capital cost of supplying electrical 
service, amounting to 50 per cent of the cost of line and secondary equipment 
necessary to deliver power from the supply point of the Commission's stations 
or of a city, town, village, etc., to the customer's property. This is the maximum 
amount provided for by The Rural Hydro-Electric Distribution Act. 



72 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Second — Authority has been granted by the Province to the Commission in 
The Rural Power District Service Charge Act, J 930, to fix a maximum service charge 
for any class of service rendered by the Commission in a rural power district. 
Where as may be the case in newly established rural power districts such maximum 
service charge is not sufficient to meet the necessary cost of service, as specified 
by the Commission, the deficit is chargeable to and payable out of the Consoli- 
dated Revenue Fund of the Province. Payments made out of the Consolidated 
Revenue Fund for this purpose, on account of any rural power district, are 
charged to that rural power district in a special account — known as the "Rural 
Power Service Suspense Account" — in the books of the Treasurer of Ontario, 
and any surplus thereafter arising from any maximum service charge in that 
rural power district is to be paid to the Treasurer of Ontario and placed to the 
credit of the rural power district in such suspense account until the deficit is 
extinguished. Where a temporary deficit arises in any rural power district owing 
to the application of the maximum service charge, such maximum service charge 
must remain in force and be charged in that rural power district until the deficit 
is extinguished. 

A tabulation set out on an accompanying page shows the present maximum 
service charge placed in effect on January 1, 1930. 

Third — An Act — The Rural Power District Loans Act, 1930 — to provide for 
granting aid towards the installation of electrical works in rural power districts 
was passed during the year 1930. The purpose of this Act is to provide advances 
towards the installation of electrical services in rural power districts, subject to 
regulations. Aid may be granted subject to such regulations and repayments, or 
the wiring from the transmission or distribution lines of the Commission into and 
throughout dwellings, farms, out-houses, and any other works which may from 
time to time be specified by the regulations. In addition to the wiring, loans may 
be obtained on transformers, motors, or other appliances, as may be necessary or 
expedient for any industrial, agricultural or domestic purpose which may be 
specified in the regulations. 



Rural Loans 

Loans have been made to rural consumers to aid them finance the cost of 
wiring their premises and the installation of motors, grain grinders, pumping 
systems, milking machines and washing machines — all made possible by the 
passing of The Rural Power District Loans Act in 1930. 

Up to October 31, 1933, there have been 496 applications for loans received 
since the Act was put into force. Of these 144 were received during the last 
fiscal year. During the fiscal year 11 applications have been withdrawn by the 
applicants, 12 have been either ineligible for loan due to the condition of the 
security or the applicants have failed to conform to the regulations — approval to 
these has not been given — and 29 applications are pending the receipt of informa- 
tion from the field to enable the Commission to approve them. In all, 371 appli- 
cations have been approved and loans granted up to October 31, 1933; of these, 
110 have been granted during the past fiscal year. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



73 



The following table shows the applications approved and granted in the 
various systems: 

APPLICATIONS FOR RURAL LOANS APPROVED AND GRANTED 



System 


To Oct. 31, 1932 


Fiscal Year 1933 


Total to date 


No. 


Amount 


No. 


Amount 


No. 


Amount 


Niagara 


166 
76 
19 


$ 

36,260 

21,727 

5,715 


93 
9 

3 

5 


$ 

17,135 

2,065 

415 

1,060 


259 

85 

22 

5 


$ 
53,395 


Georgian Bay 


23,792 


Eastern Ontario 


6,130 


Northern Districts — Manitoulin Island 


1,060 










Totals 


261 


63,702 


110 


20,675 


371 


84,377 







The average loan amounts to $227.43. 

DETAILS OF RURAL LOANS GRANTED UP TO OCTOBER 31, 1933 



Items applied for 
(including installa- 
tion) in loans 


1930-31 

74 Applications 

Granted 


1931-32 

187 Applications 

Granted 


1932-33 

110 Applications 

Granted 


Totals 

All Applications 

Granted 


which have been 
paid 


Number 
affected 


Cost to 
consumers 


Number 
affected 


Cost to 
consumers 


Number 
affected 


Cost to 
consumers 


Number 
affected 


Cost to 
consumers 


Service 


60 
63 
60 
16 
15 
6 
2 
15 


$ 

3,485 
7,861 
6,160 
1,545 
2,490 
616 
675 
1,734 


91 
90 

87 

15 

95 

8 

2 

8 


$ 

4,756 

8,077 

7,453 

1,508 

16,986 

849 

405 

934 


21 

18 

24 

7 

87 

2 

2 

2 


$ 

1,286 

1,279 

1,470 

942 

15,635 

147 

386 

159 


172 
171 
171 

38 
197 

16 
6 

25 


$ 

9,527 
17,217 
15,083 

3,995 


House wiring 

Building wiring. . . . 
Motors 


Grain grinders 

Pumping systems. . 
Milking machines.. 
Washing machines. 


35,111 
1,613 
1,466 

2,827 


Totals 


74 


24,566 


187 


40,968 


110 


21,304 


371 


86,839 



Respecting the 371 applications which have been granted, the following 
table shows the number of loans approved for each term of years from one to 
ten years: 



One year term 4 loans 

Two " " 4 " 

Three " " 24 a 

Four " " 11 » 

Five " " 203 " 



Six year term 6 loans 

Seven a " 72 " 

Eight " " 9 " 

Nine " " " 

Ten " " 38 " 

Total 371 " 



Up to October 31, 1933, 29 loans had been repaid in full, either through the 
fact that the loans matured or because of the improved financial position of the 
loanee. 

The assistance given by the Province in these several ways is in pursuance of 
a long-established governmental policy of promoting the basic industry of agri- 
culture. This policy had previously found expression in the establishment of 



74 



TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 




RURAL ELECTRICAL SERVICE IN ONTARIO 

The utility-motor chopper set up as shown permits chopping to be 

done while the operator is otherwise employed in the barn The 

line shafting, when belted to the motor, will supply power for 

many other machines used in the barn 



agricultural schools, colleges and experimental farms, in assistance for farm 
drainage, road building and in other ways. The grants-in-aid and guarantees 
thus given make it possible to extend hydro-electrical power service to those 
engaged in and connected with agricultural pursuits in less densely populated 
districts where otherwise such service would not be financially feasible. 

The extent and effect of the Province's financial assistance with respect to 
the distribution of power in rural districts should be clearly understood. The 
Government grant-in-aid relates solely to the initial capital investment for dis- 
tribution facilities in rural power districts only. Having made its grant-in-aid, 
the Government further participates in the operation of each district in that it 
guarantees a maximum service charge, otherwise its participation in the operation 
of the property ceases. Each rural power district not only pays the cost of 
operation, maintenance and administration of its lines, but also sets up reserves 
for renewals, obsolescence and contingencies on the whole of the equipment and 
lines, as well as for sinking fund on the investment made by the Commission 
on behalf of the townships served. 

The aggregate load distributed to the rural dwellers is, and possibly must 
always be, but a relatively small proportion of the total load distributed by the 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



75 




RURAL ELECTRICAL SERVICE IN ONTARIO 

Milk cooling by electric refrigeration with agitation is now being used by progressive Ontario 

farmers to their economic advantage. It is reported that this method of cooling is less 

expensive, more reliable and certainly cleaner than ice 



Commission when the amounts of power supplied to large cities and industrial 
consumers are taken into consideration, but some idea of the magnitude of the 
rural load may be conveyed by stating that it is now equal to the sum of the loads 
supplied to eight of the smaller cities served by the Commission, or to the loads 
supplied to 38 towns of population 2,000 or more. 

The accompanying diagrams and tables illustrate the expansion of rural 
electrical service in Ontario during the last thirteen years. The greater area 
covered is shown by the increased mileage of primary lines approved. The 
increase in the use of electricity by the farming communities is shown by the 
aggregate power loads supplied to the rural power districts. It is believed that 
further substantial progress will be made in the next few years. An outstanding 
reason for this growth is the extent to which the Commission has gained the 
confidence of the rural communities through efficiency in the construction of 
lines, through progressive reductions in rates and by a continuity of service which 
has contributed very materially to progress by inspiring confidence in the use of 
electrical power-driven machinery. 

Further research investigation of equipment for use on the farm has been 
carried on by the Commission's engineers in an effort to improve the efficiency 
of the application of Hydro power to the needs of the Ontario farmer and to 
develop new uses to their advantage. Plates for grain choppers have been 
further improved and new developments in the utility motor chopper have been 
started by manufacturers in co-operation with the Commission. Milk coolers 
employing the agitation principle have been produced which achieve the desired 



76 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



MILES 
15.000 



10.000 



5.000 



JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAM 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
OEC 

FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 


t 1 M 1 II M M II M M II | M M M M M " ~- 

i j RURAL POWER DISTRICTS 


TOTAl Mil FAflF OF 


RURAL PRIMARY LINES APPROVED 


ALL SYSTEMS 


HYDRO-ELECTRIC POWER COMMISSION 


OF ONTARIO 


• 






1 
_ _ . 1QQQ ._ 


i yoo ' — 

1 Q10 1 


1 yoz. 


lyoi - 


,'" 


=-*=^ 1Q*3H- 


- i * you ^_ 


^ 7 


1Q9Q -X- 


\ y^y j 


_ _ _ _ -1QOQ- ^—— - - - 


-ly^o ^'- , 


- 1 Q07 -'' 


I \ic. 1 "?"* 


iqoc . •_ >* — ! !" 


- ly^b L^ 


-b-"^*""" \Ck*>A 1Q9^ 




~ iy^i^ y^o ^.- s - 


- 1 921 - , 


-- 'T 


FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 

FEB 
MAR 
APR 

JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 

FEB 

MAR 
APR 

JUNE 

AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 

AUG 
SEPT 
OCT 
NOV 
DEC 



15,000 



10,000 



5.000 



RURAL T LINE EXTENSIONS DURING THE YEAR 1933 





Miles of 
primary- 
line 


Number of consumers 


Power 
supplied 

in 

October, 

1933 


Capital approved for 
extensions 


System 


Hamlet 


Farm 


Total 


Total 


Provincial 
grant-in-aid 


Niagara 


113.76 
40.23 
58.74 
26.65 

2.73 
4.40 


775 
312 
3C7 

55 

23 
43 


512 
118 
154 

5 

1 
6 


1,287 

430 

461 

60 

24 
49 


24,296 

2,473 

5,329 

113 

81 
80 


$ c 

274,682.00' 

101,482.94 

151,051.00 

48,183.00 

7,086.00 
8,377.00 


$ c 
137,341.00' 


Georgian Bay 

Eastern Ontario. . . . 

Thunder Bay 

Northern Ontario 
Properties: 
Nipissing District 
Manitoulin District 


50,741.47 
75,525.50 
24,091.50 

3,543.00 
4,188.50 


Total 


246.51 


1,515 


796 


2,311 


32,372 


590,861 .94 


295,430.97 







1934 



HYDRO-ELECTRIC POWER COMMISSION 



77 



HORSEPOWER 



HORSEPOWER 



60.000 



i 

> 
> 

JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUO 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC 
JAN 
FEB 
MAR 
APR 
MAY 
JUNE 
JULY 
AUQ 
SEPT 
OCT 
NOV 
DEC 


uu.uuu ; " ■ I I I I l l l l I I i i i i i I I l l l l i l 


A^ftRF^ATF PFAK" 1 flAn^ 


ALL SYSTEMS 


HYDRO-ELECTRIC POWER COMMISSION 


OF ONTARIO 












1QOO 


1 Q0 1 W> j*- 


1931 ' f A f S 


I \ 4- \— - i- -^ - qWo- 


I ^\ / > t yJ ° 


30.000 -"\ V -j- 


V 4 W ^J 1Q9Q J N 


V / 1 


y. ^ ti i 


t >> \ ' 


IU.UUU - - "Ii7^0" ~j ~^sJj " 


1Q07. / V _A 


J C. 1 ~S" ^-7 


- QPfi £"^ ^-£ 


l9fcO r ^^ 


-n^ -1Q9/1 




iQOO 1 1 ?*"""* > ** 


rr+t '92i 1 1 1 1 1 NniUil^kftiTm 




FEB ~ 

MAR 

APR _ 

MAY 

JUNE 

JULY 

AUG 

SEPT 

OCT ~ 

NOV 

DEC 

JAN 

FEB 

MAR 

APR 

MAY 

JUNE 

JULY J 

AUG J 

SEPT 1 

OCT 

NOV 

DEC 

FEB ~ 

MAR 

APR 

JUNE ~~ 
JULY _ 
AUG 
SEPT 
OCT 
NOV 
DEC ~~ 
JAN _ 
FEB _ 
MAR _ 
APR _ 

JUNE _ 
JULY _ 
AUG 
SEPT 
OCT 
NOV 
DEC — 
JAN _ 
FEB _ 

APR ~ 
MAY _ 
JUNE _ 
JULY 
AUG 
SEPT 
OCT 
NOV 
DEC — 



50.000 



40.000 



30.000 



20.000 



10,000 



SUMMARY OF RURAL LINE EXTENSIONS 
As Approved by the Commission from June 1, 1921, to October 31, 1933 



System 



Miles of 

primary 

line 



Number of consumers 


Capital approved for extensions 


Hamlet 


Farm 


Total 


Total 


Provincial 
grant-in-aid 



Niagara 

Georgian Bay 

Eastern Ontario 

Thunder Bay 

Northern Ontario Proper- 
ties: 

Nipissing District 

Manitoulin District. . . 

Total 



6,581.34 


22,405 


22,135 


44,540 


826.18 


4,044 


1,777 


5,821 


1,637.16 


6,769 


3,969 


10,738 


77.20 


111 


150 


261 


15.12 


293 


29 


322 


37.40 


143 


20 


163 


9,174.40 


33,765 


28,080 


61,845 



* c 

14,528,882.63 

1,726,687.95 

3,612,244.79 

135,300.00 



44,094.00 
62,923.00 



20,110,132.37 



$ c 

7,241,161.31 

829,681.99 

1,806,122.39 

67,650.00 



22,047.00 
31,461.50 



9,998,124.19 



78 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

result in a minimum of time. The Commission's engineers, in co-operation with 
the Agricultural Engineering department of the Ontario Agricultural College at 
Guelph, have jointly made studies and suggestions in the perfecting of this 
equipment. 

During the past year electrical soil heating was the subject of research in 
regard to its use on vegetable growers' farms at Burlington, Vineland Testing 
station and the Ontario Agricultural College. Investigations were also made in 
order to show the variety of uses to which electrical soil heating might be applied 
by vegetable growers, florists, etc. These investigations were actually carried 
out in the tobacco seed propagating beds at Simcoe, in the propagating flower 
beds at Niagara Falls, also in the open vegetable fields in the vicinity of 
Collingwood and Burlington. 

Co-operation with the Ontario Government Emphasizing the 
Importance of "Ontario Products for Ontario People" 

The Ontario Department of Agriculture arranged during the year to conduct 
cooking schools in various centres throughout the Province. These schools were 
for the purpose of emphasizing the importance of "Ontario Products for Ontario 
People." At the request of the Minister of Agriculture the Commission co- 
operated with the Department by setting up for demonstration purposes electrical 
apparatus for the kitchen such as cooking appliances, refrigerators, etc. This 
equipment was loaned by the various manufacturers and two-day electric cooking 
demonstrations were held in various centres as follows: Aylmer, Brampton, 
Brighton, Exeter, Lindsay, Milton, Napanee, Newmarket, Orangeville, Port 
Hope, St. Marys and Stratford. 

Considerable interest in the information provided was apparent as these 
classes had an average attendance of 250. In two cases severe weather interfered 
with the attendance. The places at which these demonstrations were given were 
selected with a view to providing information for the smaller towns and rural 
districts; as it was considered that the cities and larger towns were already well 
informed through demonstrations by the various manufacturers of electrical 
apparatus. 

The Year's Constructional Activities 

During the past year the amount of constructional work carried out in the 
rural power districts was much lower than that obtaining a few years ago. Never- 
theless some 250 miles of primary transmission lines were constructed or under 
construction and electrical service was given to more than 2,300 additional 
consumers. The capital expenditure approved for rural construction work during 
the past year was $590,862, and the aggregate peak load in October, 1933, reached 
32,372 horsepower. Details of these matters and of the present status of rural 
distribution are presented in the accompanying tables. For the coming year, 
arrangements have been made to construct about 300 miles of additional rural 
lines. 

The tabulation on page 76 shows the extensions approved during the year, 
the number of consumers, the amounts of power supplied, the capital expenditures 
and the amounts of provincial grant-in-aid of rural lines approved by the 
Government. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



79 




RURAL ELECTRICAL SERVICE IN ONTARIO 

Electric soil heating by cable heater units installed on or under the soil of propagation or 

growing areas, produces surprising results in advancing and increasing the harvest. Control, 

automatically or at the will of the operator, provides flexibility formally not available to the 

grower. This is a comparatively new field of application for Hydro-electric power 



Rates for Rural Electrical Service 

Rates to rural consumers are based upon service "at cost" — proper account, 
of course, being taken of the Provincial grant-in-aid for rural work and the 
operation of the provision for a maximum service charge — and as in urban centres 
the rates are made up of two parts, a service charge and a consumption charge. 
In any given rural power district the service charge to a consumer depends 
primarily upon the individual connected load or demand which determines his 
class rating (see "Classification of Services") but this is modified in the earlier 
years of operation of a rural power district by the provision respecting maximum 
service charge; the consumption charge is in the form of a first and second 
kilowatt-hour charge and is largely determined by the cost of power at the source 
of supply to the rural power district. 

An important factor in connection with rural power supply is the stability 
of rates charged. Since service is given at cost and since it is the policy to give 
service whenever economically practicable, it is necessary, in the interests of the 
rural consumers themselves, to ensure by contract a certain minimum return 
from each mile of line constructed. Otherwise, if one or two prospective consumers 
failed to take service, it would place an unfair burden upon those who did. 
Experience has led the Commission to adopt the safe policy of constructing rural 
lines only when sufficient contracts have been signed to guarantee payment of the 



80 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 




RURAL ELECTRICAL SERVICE IN ONTARIO 

In this installation the saw is being driven by a 3- horse- power motor. The motor can also 
be belted to the chopper or to a lineshaft for driving other power-using equipment. Belted- 
motor chopper installations are in many cases being superseded by utility-motor choppers 

requiring only half the power 



fixed charges on their cost; the minimum signed contracts required being three 
ordinary farm contracts or their equivalent per mile of line constructed. 

For the purpose of determining the service charge, each mile of line is assumed 
to represent a minimum of 15 units and to each class of service is assigned a 
value in such units. The accompanying table gives this information and shows 
the annual and monthly service charges applicable to each class of service. It 
may be stated that more than 90 per cent of the contracts entered into for farm 
service are either of Class 2B or Class III. These, therefore, are the representative 
classes for individual farm service. 

Rather more than half the consumers in rural power districts are grouped in 
hamlets or small villages closely identified with rural activities, and these con- 
sumers are usually in Class IB or Class 1C. It should further be understood that 
rural power districts do not include suburban districts or larger villages. These 
have their own electrical utilities. 

Usually new rural power districts begin at standard rural rates and these 
constitute the maximum rates submitted to the proposed consumers. As the 
average number of consumers per mile of line increases, the service charges may 
be, and in practice have been, reduced; and with increased consumption the 
rates per kilowatt-hour are also lowered. Thus, in older-established rural power 
districts the total cost of service is much below the initial standard rates. 

At the end of this section is given a tabulation of the rural power districts 
established in connection with the several systems of the Commission, which 
shows the miles of line, the number of consumers and the rate schedules for each 
district. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



81 




RURAL ELECTRICAL SERVICE IN ONTARIO 



Present pumps may be adapted to electric 

drive by using a jack belted to a motor, 

usually with a supply tank at a height 



The automatic electric pump used in rural 
districts, assures a water service equal to 
that in towns and cities. In the equipment 
shown, the pump is automatically started 
when the pressure in the small tank falls 
below a certain level 



SERVICE CHARGES IN RURAL POWER DISTRICTS— SINCE JAN. 1, 1930 
With Provincial Grant-in-Aid — 25-cycle and 60-cycle Service 







Approx. 




Kilowatt- 










Class 


Units 


number 


Demand 


hours 


Gross 


Gross 


Net 


Net 


of 


per 


of 


allowed 


per 


annual 


monthly 


annual 


monthly 


rural 


con- 


customers 


consumer 


month 


service 


service 


service 


service 


service 


sumer* 


per mile 
of line 


in k-w. 


at 
first rate 


charge 


charge 


charge 


charge 












$ c. 


$ c. 


$ c. 


$ c. 


IB 


2.25 


6.8 


1.32 


30 


18.00 


1.50 


16.20 


1.35 


1C 


3.75 


4.0 


2.0 


30 


27.96 


2.33 


25.20 


2.10 


2A 


1.90 


8.0 


1.32 


30 


20.64 


1.72 


18.60 


1.55 


2B 


3.50 


4.3 


2.0 


30 


27.96 


2.33 


25.20 


2.10 


3 


5 00 


3 


3.0 


42 


33 36 


2.78 


30 00 


2.50 


4 


5.35 


2.8 


5.0 


70 


36.00 


3.00 


32.40 


2.70 


5 


7.50 


2.0 


5.0 


70 


50.04 


4.17 


45.00 


3.75 


6A 


12.50 


1.2 


9.0 


126 


62.04 


5.17 


55.80 


4.65 


6B 


12.50 


1.2 


9.0 


126 


70.68 


5.89 


63.60 


5.30 


7A 


20.00 


0.74 


15.0 


210 


92.64 


7.72 


83.40 


6.95 


7B 


20.00 


0.7 


15.0 


210 


111.36 


9.28 


100.20 


8.35 



*Before a rural primary line is constructed contracts equivalent to 15 primary units per 
mile must be signed. (For explanation of units see accompanying text.) Thus three Class 3 
consumers at 5 units each equals 15 units. Service charges are adjusted so that each class of 
service bears its equitable share of the cost. 

Note: For classification of services see page 88. 



82 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



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88 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



CLASSIFICATION OF SERVICES FOR RURAL POWER DISTRICTS 

When contracts between the consumer and the township have been executed, 
users of power in townships are supplied with electric service under general classes 
with limitations as follows: 



Class 



Service 



Class 
demand 
kilowatts 



Phase 



Volts 



Fuse rating 

amperes 
(maximum) 



IB 
1C 

2A 

2B 

3 

4 

5 

6A 

6B 

7A 

7B 



Hamlet Lighting 

u a 

House Lighting 

Small Farm Service. . . 
Light Farm Service . 
Medium Farm Service 

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Heavy Farm Service. . 

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Special Farm Service. . 



1.32 

2 

1.32 

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3 

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5 

9 

9 
15 
15 



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1 

1 and 
1 

1 and 



110 
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110 
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220/110 
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220/110 
220/110 
220/110 
220/110 
220/110 



15 

35 

20 

35 

35 

50 

35 
100 

60 
According to load 
According to load 



Class 1: Hamlet Service — Includes service in hamlets, where four or more consumers are 
served from one transformer. This class excludes farmers and power users. Service is given 
under two sub-classes as follows: 

Class 1-B: Service to residences or stores. Use of appliances over 1,320 watts 
permanently installed is not permitted under this class. 

Class 1-C: Service to residences or stores with electric range or permanently installed 
appliances greater than 1,320 watts. Combinations of residence and store supplied from 
one service shall be not less than Class 1-C. Special or unusual loads will be treated 
specially. 

Class 2A: House Lighting — Includes service to all residences that cannot be grouped 
as in Class I. This class excludes farmers and power users. 

Class 2B: Farm Service, Small — Includes service for lighting of buildings and power for 
miscellaneous small equipment and power for a single-phase motor not exceeding 2 horsepower 
or an electric range (motor and range not to be used simultaneously) on a small farm of fifty 
acres or less. 

Class 3: Farm Service, Light — Includes service for lighting of farm buildings, 
power for miscellaneous small equipment, power for single-phase motors not exceeding 
3 horsepower and electric range. Range and motor are not to be used simultaneously. 

Class 4: Farm Service, Medium Single-Phase— Includes service for lighting of farm buildings 
and power for miscellaneous small equipment, power for single-phase motors up to 5-horsepower 
demand or an electric range. Range and motor are not to be used simultaneously. 

Class 5: Farm Service, Medium 3-Phase — Includes service for lighting farm buildings 
and power for miscellaneous small equipment, power for 3-phase motors, up to 5-horsepower 
demand, or an electric range. Range and motor are not to be used simultaneously. 

Class 6: Farm Service, Heavy — Includes service for lighting of farm buildings and power 
for miscellaneous small equipment, power for motors up to 5-horsepower demand and an electric 
range, or 10-horsepower demand without an electric range. Single- or three-phase service will 
be given at the discretion of the Hydro-Electric Power Commission of Ontario. 

Class 7: Farm Service Special — Includes service for lighting of farm buildings, power 
for miscellaneous small equipment, power for 3-phase motors from 10- to 20-horsepower demand 
and electric range. Single or three-phase service will be given at the discretion of the Hydro- 
Electric Power Commission of Ontario. 



Note: Class 2B is the service usually supplied to small farms of fifty acres or less and Class 3 
is the service usually supplied to ordinary farms of larger size. More than 90 per cent of new 
contracts for farm service are in one or other of these two classes. 



1934 HYDRO-ELECTRIC POWER COMMISSION 89 



SECTION IV 



HYDRAULIC ENGINEERING AND CONSTRUCTION 



The advancement of the Abitibi Canyon development to the operating stage 
was responsible for the major items of design and construction during the year. 
After resuming construction as the agent of the receiver for the company, after 
financial difficulties had caused a cessation of work, the Commission carried on 
when the province of Ontario acquired the development. 

The original plans of the company provided for the immediate completion 
of the whole development, which was designed to accommodate five units of 
66,000 horsepower each. The major part of the work was completed before the 
shut-down referred to above, the dam, wing walls, sluices, high water channel 
and power house substructure being practically completed. The programme, 
as modified after the Province acquired the property, provided for the completion 
of two units to the operating stage, and other necessary work in connection 
therewith. The units came into service and delivered commercial power in the 
summer of 1933. 

At the Niagara Falls plants, only minor items of construction, completing 
work commenced in the previous year, required attention. At Chats falls, 
extensive efficiency and capacity tests were conducted. The arbitration in 
connection with the Kingdon Mining and Smelting company involved a large 
amount of field and office work as assistance to the Legal department. 

In the Georgian Bay system, repairs were made to the dam at Walkerton, 
and investigations were made of wood-stave pipe joints, preparatory to the 
reconstruction of No. 1 wood-stave conduit at the Eugenia development. Repairs 
were also made to concrete in the dam at Nipigon. 

At the request of the Public Utilities commission of the town of Almonte, 
plans and specifications were prepared for an extension of the town's power plant 
by the installation of an additional unit. The Commission's engineers also gave 
advice during the completion of the contract for the new equipment, and made 
inspections during its fabrication. 

Surveys were made and plans and estimates prepared in connection with 
the construction of a development to supply power to mining properties in the 
district of Patricia. 

Further assistance was given to the Department of Lands and Mines in 
connection with the Grand river conservation scheme. 



90 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

NIAGARA SYSTEM 

Queenston-Chippawa Development 

The end of the last fiscal year found certain minor works in progress on the 
Queenston-Chippawa development, which were completed shortly after that time. 
Among these were repairs to the Michigan Central Railroad bridge over the power 
canal at Montrose, and work on the Victoria Avenue bridge. 

Ontario Power Plant 

At the Ontario Power plant, scaling of loose rock from the cliff behind the 
generating station continued, and was completed at the end of December. A dry 
stone wall was also built on the rear wall backfill to protect the power house 
roof from any material on the cliff that may become loosened by weathering and 
be dislodged. This and certain site improvements were completed early in 
January. 

An inspection of the steel plate of certain of the penstocks was made, and a 
report prepared on the protective measures to retard deterioration of the outer 
surface. The penstocks at the Ontario Power plant are erected in shafts and 
tunnels, extending downward and outward from the three main conduits. Five 
shafts and tunnels house penstocks Nos. 1 to 10, two in each tunnel. In a number 
of the tunnels, the void around the penstocks has been filled with concrete to 
protect the penstocks. The inspection referred to was carried out in the other 
tunnels, for the purpose of determining the necessity, and the measures to be 
adopted, for preservation of the unprotected penstocks. 

Chats Falls Development 

Only minor items of construction work were carried out during the past year, 
the plant having been completed during the previous year. Hydraulic tests of 
various kinds were conducted, having in view the determination of the turbine 
capacity and efficiency, the plant capacity under low head, and the plant capacity 
at periods of low flow. 

Turbine efficiency and capacity tests were conducted on unit No. 3. Units 
4, 7 and 8 had been tested in the previous year, and on these, consistent results 
were obtained. The tests on unit No. 3 confirmed the results obtained on the 
other units. 

The quantity of water used per unit at this plant is in excess of 6,000 cubic 
feet per second at full gate. The quantity of water to be measured and the design 
of the plant combined to make accurate measurements more difficult than is 
usually the case. The Gibson time-pressure method of water measurement had 
been applied in the majority of the tests conducted by the Commission, especially 
in those cases where a reasonable length of supply pipe was available within which 
the method might be applied. The supply pipes at Chats falls are much shorter 
than any in which the method had been used previously, but application of the 
method proved to be quite successful, in fact the results obtained on the different 
units were unusually consistent. The results of these tests, in addition to deter- 
mining that the turbines met the manufacturers' guarantees, provide information 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



91 




WALKERTON DAM— SAUGEEN RIVER 
Spillway and apron cribs 



of great value in connection with operation of the plant to obtain the maximum 
output from the available quantity of water. The tests also permit accurate 
records of river discharge to be kept. 

Assistance was given to the Legal department in connection with the arbitra- 
tion on the claims of the Kingdon Mining and Smelting company for compensation 
for lands expropriated and for damages to lands and mining properties. The 
hearings in connection with this arbitration lasted for more than sixty days, and 
involved a very great amount of computation and field work on the part of this 
department. 



GEORGIAN BAY SYSTEM 



Inspection of the wood-stave conduit installed in 1914 at the Eugenia develop- 
ment indicates that its replacement will be necessary in the near future. The 
Commission's experience during the past twenty years with wood-stave pipes has 
indicated certain weaknesses in the usual type of end joints used. Accordingly, 
with the co-operation of manufacturers, investigations have been proceeding for 
some months on designs and devices to overcome the tendency of the stave ends 
to split or rot. It is proposed to build a section of pipe incorporating the various 
designs of joints, and subject it to suitable tests. 

Repairs were carried out on the dam on the Saugeen river at Walkerton. 
Erosion under and downstream from the dam allowed leakage to take place 
equivalent to the water capacity of one of the turbine units. Several attempts 
to plug the leak have been made by former owners, but in none of these was 
anything more than temporary relief obtained. 



92 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



As the erosion had taken place in the vicinity of the original sluiceways, the 
sluiceway was closed and converted into a spillway, below which apron cribs were 
built. Cribs were built on the east bank to protect the land there from erosion 
when the sluiceways are open. Protecting cribs were built also in an eroded area 
downstream from the sluiceways. 

A disused narrow-gauge railway bridge near the Hanover plant, communi- 
cating with marl beds west of the river, which created a flood hazard, was removed. 




ABITIBI CANYON POWER DEVELOPMENT 
Forebay, dam and sluice gate from west shore above dai 



NORTHERN ONTARIO PROPERTIES 



Abitibi Canyon Development 

The major items of construction work during the year were in connection 
with the Abitibi Canyon development, which has now reached the operating 
stage. This development, on the Abitibi river, is situated near Fraserdale, 
sixty-five miles northerly from Cochrane. Construction was commenced in 
1930 by the Ontario Power Service corporation, a subsidiary of the Abitibi 
Power and Paper company. Active construction ceased in the summer of 1932, 
due to financial difficulties. The Ontario Power Service corporation was placed 
in a receivership in November, 1932, and construction of the Canyon develop- 
ment was continued by the Commission for the Receiver until the development 
was taken over by the province of Ontario early in 1933. 

Active construction commenced in August, 1930, and by July, 1932, when 
financial difficulties caused the work to be shut down, the plant was rapidly 
nearing completion. The concrete in principal structures was all in place, except 
for about 850 cubic yards in the dam, the wing walls at each end of the dam, 
and a small protection wall on the down-stream side of the dam. An additional 
3,000 cubic yards of concrete was required for bulkheads behind the closure 
gates in the unwatering tunnels, and tailrace excavation to the extent of 57,000 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



93 




ABITIBI CANYON POWER DEVELOPMENT 
High water channel, looking downstream to river 




ABITIBI CANYON POWER DEVELOPMENT 
Tailrace from Power House — December, 1933 



94 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 




1934 HYDRO-ELECTRIC POWER COMMISSION 95 

cubic yards was still to be removed. The erection of the hydraulic units and 
equipment was about 70 per cent completed, and nearly everything was delivered 
for units 1 to 4, as well as a large part of unit No. 5. Delivery and erection of 
electrical equipment was not as far advanced. The power house roof and part 
of the downstream wall were temporary structures only. 

The decision was reached to continue construction so far as to place two 
units in operating condition, the equipment for the remaining three units being 
stored at the development, to be used when load conditions required their 
installation. Work was prosecuted vigorously from the beginning of the fiscal 
year, November 1, 1932, and by the end of March the tailrace excavation was 
completed and the cofferdam and rock at the lower end of the tailrace removed 
by blasting. The power house superstructure was practically completed, with 
the exception of the application of the roofing material and the guniting of the 
slabs over the penstocks. 

Good progress had been made on the installation of equipment. Turbine 
unit No. 1 was in place and aligned, the generator unit in place, and the bearing 
being assembled. All governor piping in the turbine pit, including servomotors, 
had been opened up and thoroughly cleared, and the cleaning of the governor 
piping above the power house floor was in progress. Work was proceeding on 
unit No. 2. 

Unit No. 1 was turned over for the first time on May 4, and delivered 
commercial load on May 24, 1933. No. 2 unit was placed in service on August 
27, 1933. A description of the development follows. 

The Abitibi Canyon development is situated on the Abitibi river in the 
James Bay drainage area, about sixty-five miles northerly from Cochrane. The 
river drains an area of 8,440 square miles above the power site, and has an 
estimated average flow of more than 9,000 cubic feet per second. The site 
possesses natural advantages for the construction of a power development, in 
that the river channel there is confined to a narrow gorge, the rock walls of 
which rise about 170 feet above the river bed. The dam concentrates the natural 
fall in about six miles of river upstream therefrom, and the tailrace excavation 
regains most of the fall from the dam site to the pool at the head of Eleanor 
rapids, about three-quarters of a mile downstream. The normal headwater 
level will be 641, and normal tailwater 401, and the head 240 feet. The 
accompanying plan supplements this description and shows the relative positions 
of the various structures and waterways. 

The dam is a concrete gravity type structure, extending across the main 
section of the canyon, with a sluiceway section adjoining it at the easterly end. 
The closure is completed by a concrete retaining wall and rolled earth fill at 
the west end of the dam, and a similar retaining wall and earth fill at the east 
end of the sluiceway section. 

The sluiceway section, which is designed to discharge the maximum 
anticipated flood discharge of the river, consists of five gates, each having a 
clear opening of 45 feet, with sills at elevation 616, each provided with an 
independent motor-driven hoist. Heaters are provided for the checks, and 
space heaters in the gates, which are sheeted on the downstream face, to assure 



96 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

satisfactory winter operation. The sluiceways discharge into a high water 
channel, extending for about 3,000 feet along the east bank of the river, and 
discharging into the pool above Eleanor rapids. The high water channel is 
located well back from the edge of the east bank of the canyon . and is formed 
partly by excavation in rock and partly by the construction of gravity wall 
sections along the sides where necessary to prevent overtopping. 

The power house extends completely across the gorge and adjoins the main 
dam section. The generator room is about 250 feet by 50 feet, and in the rear 
of this, partly superimposed on the lower slope of the dam, is accommodation 
for control room, offices, low tension switching, machine shop, pumps and other 
auxiliaries. An elevator in a shaft on a slope, which conforms to the downstream 
face of the dam, extends from the turbine deck to the headworks. 

The power house is designed for an ultimate installation of five main units, 
two of which are now completed. Each of the turbines has a rated capacity of 
66,000 horsepower at 150 r.p.m. under a net head of 237 feet. Each turbine 
is equipped with an 18-foot steel plate penstock, the intake being located in the 
upper portion of the gravity section of the main dam, whence the penstocks 
lead down from the face of the dam to the power house substructure, where they 
are joined to the steel plate scroll cases incorporated therein. The penstocks 
are protected from low temperatures by a continuous roof, which extends over 
the entire penstock area. This roof is supported on steel columns, and consists 
of I-beam purlins carrying aerocrete slabs, which are protected from the weather 
by a heavy coating of gunite. 

Each turbine is directly connected to a 45,000 kv-a., 85-per-cent-power- 
factor, 13,800-volt, 25-cycle generator, with main and sub-exciters. 

The plant is served by a standard gauge railway spur from the site to 
Fraserdale, where it joins the T. and N.O. railway. Accommodation for the 
operating staff is provided in houses erected on high ground on the west bank 
of the river. 



HYDRAULIC INVESTIGATIONS 

Mississippi River 

During the year, the Public Utilities commission of the town of Almonte 
asked for engineering assistance in connection with an extension of its power 
development on the Mississippi river within the town. The town owns two 
plants, only one of which is operated at present. This plant contains a single 
unit, having a turbine with a rated capacity of 550 horsepower and 550-kv.a. 
generator, but the power canal and power house substructure are designed for 
the installation of a second unit. 

The Commission's engineers made an examination of the existing plants, 
and gave advice as to the type of equipment that would be most suitable for 
the town's requirements. Following this, plans and specifications were prepared 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



97 





KAGAMI FALLS— ALBANY RIVER 
An undeveloped power site in Northern Ontario 



covering one 650 horsepower (30-foot head) turbine and generator, with governor 
and other appurtenances. Tenders were called for on this equipment and advice 
given in connection with the completion of the contract and inspections made 
throughout the period of fabrication of the equipment. 



Albany River 

Pursuant to requests for studies and estimates for power supply required 
by certain mining properties in the district of Patricia, preliminary surveys 
were made of three possible power developments on the Albany river. The 
locality for which a power supply is desired lies about ninety miles by aeroplane 
north of Savant lake station on the Canadian National railway, and one hundred 
and twenty miles by winter road. 

Three power sites on the Albany river, about twenty-five miles south of 
the properties to be served with power, were investigated in the summer of 
1933, and preliminary surveys made, with a view to estimating the cost of 
developing about 1,000 horsepower, the anticipated demand of the district. 
The three sites surveyed are Cedar rapids, at the outlet of lake St. Joseph, and 
Triple falls and Kagami falls, respectively twenty and twenty-five miles down- 
stream. At each of the first two, the available head is 15 feet, and at Kagami 
falls 21 feet. Transportation of material and equipment to the sites is difficult 
and expensive. Heavy parts may be taken in only by winter road; for general 
supplies, aeroplanes may be utilized. The plants, therefore, are designed as 
far as possible to reduce transportation costs. Preliminary designs and estimates 
have been prepared. 



98 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Grand River Flood Prevention 

Assistance was given to the Department of Lands and Forests of the 
province of Ontario in connection with proposed storage works on the Grand 

river. 

Attention has been given to propositions for flood prevention on the river 
for many years, the Commission making certain surveys and investigations in 
that connection some twenty years ago. The Department of Lands and Forests 
requested the assistance of the Commission in a complete investigation of the 
problems of alleviating flood damage, of maintenance of a higher flow in the 
summer months, etc. A report, prepared jointly by the chief hydraulic engineer 
of the Commission and the deputy minister of the Department proposed that 
certain storage works be constructed, and investigated the effects of these in 
reduction of flood peaks and in improvement of low water flows. Subsequently, 
after submission of the report, the Legislature passed an act, known as the Grand 
River Conservation Commission act, to provide the machinery whereby the 
interested municipalities in the Grand River watershed might co-operate to 
carry out the works or any desired part of them. During the past year, progress 
has been made on further surveys, borings and examination of dam sites, and 
on the preparation of plans, specifications and estimates for the initial storage 
reservoir in the conservation scheme. 



1934 HYDRO-ELECTRIC POWER COMMISSION 99 



SECTION V 



ELECTRICAL ENGINEERING AND CONSTRUCTION 
(STATION SECTION) 

NIAGARA SYSTEM 

Generating and Switching Stations 

Generating Stations on the Niagara River — The relaying system on 
the 110, 000- volt lines at Queenston generating station is being improved and 
definite-time relays were purchased and installed on each of the generator circuits. 

MacLaren Development — The necessary engineering work was carried 
out in co-operation with MacLaren-Quebec Power Company for the receipt of 
the first block of 20,000 horsepower under contract for delivery on July 1, 1933. 

Transformer and Distributing Stations 

Niagara District — At Ontario Paper (Steam) transformer station, referred 
to in last year's Annual Report as under construction, the transformers, electric 
steam generators and all switching and controlling equipment were installed, 
and were placed in service on February 2, 1933. Each of the three electric 
steam generators is capable of generating 90,000 pounds of steam per hour and 
is designed for a pressure of 200 pounds. 

Temperature-measuring equipment indicates the hottest-spot temperature 
in the transformers and permits safe loading of the transformers on a temperature 
basis. In this way advantage may be taken of the low temperature of the 
cooling-water in winter and the transformers overloaded in order to obtain more 
steam during that season when it is required. 

There are no high-voltage oil circuit-breakers at the transformer station. 
In case of emergency the 110,000-volt line may be cleared by closing a solenoid- 
operated, single-pole, ground-switch which effectively grounds the line causing 
an oil circuit-breaker to open promptly at Queenston generating station. A 
low-voltage oil circuit-breaker is located in each steam-generator circuit which 
opens automatically to clear the respective feeder in case of ground or short- 
circuit on a generator or feeder, and in case of failure of a circulating-pump 
circuit. 

In approximately four months from the time this work was started the 
station was in service. 



100 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Late in October authority was given to proceed with the erection of a 
transformer station including an electric steam generator at Provincial Paper 
Limited plant at Thorold and another at Interlake Tissue Mills Company 
Limited plant at Merritton. These stations when completed will enable the 
respective companies to generate steam for their manufacturing processes and 
in so doing put to beneficial use, under special contracts, a portion of the system 
reserve power capacity at such times as it may be available. 

There will be one three-phase, 7,500-kv-a. transformer and a 7,500-kw. 
electric steam generator installed at each station. The generators have already 
been purchased and the transformers and switching equipment will be purchased 
in November, 1933. 

The Thorold distributing station and Corbett distributing station on the 
Dominion Power division were dismantled. Changes were made in the metering 
equipment at Empire Cotton distributing station and at Page Hersey Tubes 
Limited, Welland. 

Hamilton and Dundas District — At Hamilton Beach transformer 
station the relays on the 110,000-volt lines to Queenston generating station and 
Toronto-Strachan and Dundas transformer stations were replaced by high-speed, 
distance, directional, phase and ground relays and a fence was installed around 
the lightning-arresters. Improvements were made to the fencing at Waterdown, 
Hagersville, Decewsville and Lynden distributing stations and the electrical- 
grounding system was changed. 

Toronto and York District — At Toronto-Strachan transformer station 
relaying equipment is being installed for differential protection on the 110,000- 
volt bus, and high-speed selective relays on the high-voltage lines to Toronto- 
Bridgman-Davenoort, Toronto-Wiltshire, Hamilton-Beach and Dundas trans- 
former stations. Two 110,000-volt potential-transformers were transferred to 
the station for this purpose. The current capacity of two of the 110,000-volt 
line-entrances and part of the bus was increased. 

At Toronto-Bridgman-Davenport transformer station the high-voltage 
neutral was grounded through a water resistor and high-speed relays were 
installed on the 110,000-volt line to Toronto-Strachan transformer station. 
Changes were made in the 13,200-volt cable-connections. 

At Toronto- Wiltshire transformer station improvements were made in the 
metering and relaying equipment. High-speed relaying equipment was installed 
on the line to Toronto-Strachan transformer station for which a new 110,000-volt 
potential-transformer was purchased and installed. 

At Toronto-Leaside transformer station improvements were made in the 
relaying equipment and engineering work was carried on in preparation for 
future installation of No. 7 and No. 8 transformer banks. 

At Mount Joy and Sharon distributing stations changes were made to the 
fencing and in the latter station the current-transformers were replaced by 
larger-capacity units. 

At New Toronto distributing station the 2, 300- volt disconnecting-switches 
and lightning-arresters were replaced by more modern type units and improve- 
ments were made to the outdoor bank of three 1,500-kv-a. transformers. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



101 




ELECTRIC STEAM GENERATORS 

Two of three, 30,000-kw., 3-phase, 25-cycle, 6,600-volt steam generators for Ontario Paper 
Company. Maximum operating pressure 200 lbs. per square inch 



London District — Air filters and carbon-dioxide, fire-protection apparatus 
were installed on the synchronous-condenser at London transformer station. 

Improvements were made to the fencing and grounding system at Thames- 
ford, Ailsa Craig, Glendale, Delaware, Broughdale, and Lucan distributing 
stations. At the latter two stations necessary changes were also made in some 
of the electrical equipment. 



102 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Guelph District — The graphic wattmeters at Acton distributing station 
were replaced by more suitable type. 

Preston District — Two original 110,000-volt oil circuit-breakers were 
replaced by two of modern type transferred from Toronto-Bridgman-Davenport 
transformer station. 

Kitchener District — At Kitchener transformer station special thermal 
instruments were installed on the Kitchener municipal feeders to enable the 
total load to be read on meters situated in the municipal station. 

Stratford District — At Stratford transformer station five inadequate 
26,400-volt oil circuit-breakers were replaced. A new 450-ampere grounding 
reactor for grounding the 26,400-volt bus was purchased and installed outdoors. 
This reactor is used with the improved relaying system which was also recently 
placed in service. 

St. Marys District — At St. Marys transformer station one 110,000-volt 
oil circuit-breaker was replaced by a modern unit transferred from Toronto- 
Bridgman-Davenport transformer station. 

Woodstock District — At Beachville distributing station the necessary 
equipment for a second 13,200-volt feeder was purchased and installed. 

St. Thomas District — The work under way at St. Thomas transformer 
station last year was completed and placed in service. 

At Aylmer distributing station a 4,000-volt switching structure was erected, 
adjacent to the station, for sectionalizing the feeders to the various load centres. 

Kent Transformer Station — At Bothwell distributing station improve- 
ments were made to the fencing and grounding system. 

St. Clair District — At Watford distributing station changes were made in 
the meter connections and the graphic wattmeter was replaced. 

At Arkona and Thedford the metering equipment was altered to meter 
8.000-volt service instead of 4,000-volt service. 

At Sarnia municipal station No. 2, air-break switches were purchased and 
installed on the 26,400-volt line into the station and in the bus between No. 3 
and No. 4 banks. 

GEORGIAN BAY SYSTEM 

Severn District — Extra accommodation was provided in the operators' 
cottages at Big Chute generating station and improvements were made to the 
sewage-disposal system.. 

Eugenia District — At Kincardine distributing station a bank of three 
new 250-kv-a. transformers was purchased and installed replacing the original 
bank of three 125-kv-a. units. The latter units were transferred to system 
reserve. 

At Shelburne distributing station improvements were made to the grounding 
system, a 22,000-volt air-break switch was purchased and installed outside of 
the station and metering equipment was installed on the Hornings Mills feeder. 
At Owen Sound distributing station improvements were made to the grounding 
system. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



103 




TRANSFORMER STATION— ONTARIO PAPER COMPANY 

Outdoor layout of 110,000-volt station supplying current to 
electric steam generators 



Wasdells District — At Wasdells generating station water-connections 
were made to the Superintendent's house and generating station and a sewage- 
disposal plant was installed. 

Muskoka District — At Gravenhurst distributing station improvements 
were made to the station grounds. 

Bala District — At Bala generating station a new structure was erected 
opposite the present Bala generating station and the step-up transformers 
feeding power to Port Carling and McTier were moved from their former situation 
and installed on pads at the new structure, with the necessary switching equip- 
ment. The original structure was dismantled. 



KM TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

EASTERN ONTARIO SYSTEM 

110,000-volt Transformer Stations — Telemetering equipment was pur- 
chased and installed between Val Tetreau switching station and Ottawa trans- 
former station, the meters being placed in the latter station. The installation 
will give a graphic record of the total 110,000-volt, 60-cycle power received from 
Gatineau Power Company. 

Central Ontario District— A bank of three new current-transformers 
was installed at Ranney Falls generating station and improvements were made 
in the relaying system. 

At Heely Falls generating station changes have been made in the installation 
of the metering equipment. 

At Brighton, Lakefield, and Cobourg distributing stations changes were 
made in some of the metering equipment. 

At Millbrook, Madoc, Belleville No. 1 and Warkworth distributing stations 
and Belleville switching station improvements were made in the fencing of the 
grounds. 

At Oshawa distributing station the concrete walls of the original cooling- 
pond were removed, the hole was filled in and the grounds were levelled to 
conform with the adjacent grounds. 

At Kingston distributing station a 1,500-kv-a., three-phase transformer was 
installed, replacing a 750-kv-a. unit which was transferred to system reserve. 
The current-transformers were correspondingly replaced by larger units. 

At Kingston switching station the relaying equipment was improved. 

St. Lawrence District — At Williamsburg distributing station a second 
100-kv-a., single-phase transformer obtained from system reserve was installed 
in parallel with the present transformer. 

A new 225-kv-a. distributing station was installed at Maxville to supply 
power to the town of Maxville and the rural power district. Three 40-kv-a., 
single-phase transformers originally at Omemee distributing station were rebuilt 
for 75-kv-a. capacity and transferred to Maxville for this installation. 

At Apple Hill distributing station, 4,000-volt metering equipment was 
installed on the rural feeder supplying a portion of Maxville rural power district. 

Rideau District — At the request of the Almonte Public Utilities Com- 
mission, engineering assistance was given in the preparation of specifications 
for, and in the purchase of a new 550-kv-a. generator for its hydro-electric plant. 

THUNDER BAY SYSTEM 

Transformer Stations — A step-up transformer station was installed 
outside the Cameron Falls generating station for the purpose of delivering 
power at 33, 000-volts to Northern Empire Mines Limited about 48 miles north- 
easterly. Three 400-kv-a., 33,000/1 1,000- volt, single-phase transformers were 
transferred from the Madawaska system and used for this installation with the 
necessary switching, metering and controlling equipment. Power is supplied 
from the 12, 000- volt bus in the generating station. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



05 




TRANSFORMER STATION AT CAMERON FALLS, 
NIPIGON RIVER 



At the Northern Empire Mines Limited station, metering equipment was 
installed on the low-voltage feeders for metering the load supplied to this customer. 

Engineering and other assistance at the request of the Northern Empire 
Mines Limited was rendered the Company in the design and construction of its 
step-down sub-station. 

Port Arthur rural distributing station was installed near Port Arthur trans- 
former station to supply single-phase, 6,600-volt power to the beach district 
north-east of the city. A 75-kv-a. transformer obtained from Georgian Bay- 
system reserve was used. 

Fort William rural distributing station was installed to supply 8,000-volt, 
three-phase power to Fort William rural power district from the 2, 300- volt 
distribution lines. Three new 50-kv-a., 4,600/2,300-volt single-phase trans- 
formers were purchased for the installation. 

At Port Arthur rural distributing station, which supplies single-phase power 
to the rural power district north of High street, a 37}^-kv-a., 2, 300/4, 600- volt, 



106 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

single-phase transformer was purchased and installed in the feeder to permit 
grounding it, and to isolate it from the ungrounded distributing system. 

At Port Arthur transformer station high-speed relaying equipment was 
installed on the 110, 000- volt and 22, 000- volt lines terminating at the station. 
A rearrangement of the switching equipment was made on the three out-feed 
110,000-volt lines. 

At the Great Lakes Paper Company's plant at Fort William two electric 
steam generators and 2, 300- volt switching, controlling and metering equipment 
were installed and placed in operation under a contract with the company which 
permits it to utilize reserve electric power capacity at such times as it may be 
available, to generate steam required in its manufacturing processes. The 
electric steam generators are each rated at 8,000 kw., 2,300 volts, and are suitable 
for operation under 200 pounds steam working pressure. The Company is 
using its own transformers to supply the power to the generators from the Com- 
mission's 110,000-volt lines. 

At the Provincial Paper, Limited, plant at Port Arthur a 24,000-kv-a. 
transformer station is being installed for a similar purpose. Two 12,000-kv-a., 
60-cycle, three-phase, 110, 000/6, 600- volt transformers and two 12,000-kw. 
electric steam generators have been purchased and will be installed and in 
operation by the middle of November. 

NORTHERN ONTARIO PROPERTIES 

Abitibi District — The necessary generators, transformers and switching 
equipment were installed and placed in operation at Abitibi Canyon development 
to make available 55,000 horsepower as required for the customers on the system. 

Studies and estimates were prepared in connection with the supply of 
power to prospective customers. (See Frontispiece.) 

Sudbury District — At Stinson generating station improvements were 
made in the synchronizing, relaying and switching equipment. 

At McVittie generating station, No. 1 generator was rebuilt with new 
armature coils. Surge-absorbers were purchased and installed on the Burwash 
feeder and improvements were made in the grounding system at the station. 

At Coniston generating station improvements were made in the relaying 
and grounding system. 

At Sudbury distributing station a spare 1,000-kv-a., single-phase transformer 
was purchased and installed. The 22,000-volt lightning-arrester was replaced 
by a more suitable unit. 

Manitoulin District — Kagawong distributing station was erected on the 
site of Little Rapids Pulp Company's Kagawong development on Manitoulin 
island to supply power to the Manitoulin rural power district at 11,400 volts. 
Three 100-kv-a., single-phase, 60-cycle, 7, 200/600- volt transformers were 
purchased for this installation. 

ADMINISTRATION BUILDING 

Tenders for the construction of an administration building were received 
and a report thereon was prepared. The construction of the building however 
was deferred by the Commission. 



1934 HYDRO-ELECTRIC POWER COMMISSION 107 



SECTION VI 



TRANSMISSION, DISTRIBUTION AND RURAL SYSTEMS 

TRANSMISSION SYSTEMS 

The activities of the Commission's transmission section have been confined 
largely to minor detail improvements within the various systems, and to con- 
solidation and recording of extensive construction programs and of purchases 
in previous years. Certain works of major importance were completed, notably 
the extension of the 220,000-volt system to the Ottawa river at Cumberland, 
where it connects with the line of the James MacLaren Company Limited from 
the Masson development on the Lievre river, Quebec; the building of 48 miles 
of 33, 000- volt line out of Cameron Falls transformer station, Nipigon river, to 
serve the Northern Empire Mines Limited, and the serving of stations to generate 
steam electrically. 

The transmission system, recently purchased by the Commission, which 
carries power from the Canyon development on the Abitibi river was taken 
over and incorporated in the Northern Ontario properties. 

Work has progressed in the reinforcement of telephone and railway crossings 
in the various systems in conformity with the Board of Railway Commissioners' 
regulations. 

The following synopsis relates to the work undertaken during the year. 
At the back of this report a map is included showing transmission lines and 
stations and relative data are tabulated in Appendix II. 

NIAGARA SYSTEM 

220,000-volt Lines 

Between a point on the Ottawa river opposite Masson and Cumberland 
junction, a length of 1.33 miles of single-circuit, 220,000-volt, steel-tower line 
was completed. This line is of similar construction to other 220,000-volt lines 
of the Commission and was designed to transmit power from the Masson Power 
Development of the James MacLaren Company Limited to the Niagara system. 

110,000-volt Lines 

Between a junction established at Holland road and the Ontario Paper 
Company's plant at Thorold 0.66 mile of single-circuit 110,000-volt steel- tower 
line was completed. 



108 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

44,000-volt Lines 

Between Burlington and Oakville, 10.9 miles, the former D. P. & T., single- 
circuit, wood-pole line was removed, service to Oakville now being made over 
the Commission's circuits reported in 1932. 

26,400-volt Lines 

Between Tilbury junction and Fletcher junction a portion of the 26,400-volt 
circuit was removed from the telephone poles adjacent to the railway and placed 
on a pole line which had been previously constructed on roads, for rural circuit 
requirements. The revisions also included the relocation of switches and the 
replacement of a small portion of steel cable with No. 2 steel-reinforced, aluminum 
cable. 

Rehabilitation of 5 sections of single-circuit, wood-pole line totalling 28.25 
miles was completed in the vicinity of Dundas-Hagersville, Caledonia and 
Decewsville. These lines had been in operation since 1912 and poles, cross arms, 
etc., in most cases, were replaced. 

Other Lines 

At Brittania Junction two obsolete 13,200-volt air-break switches were 
replaced by a modern type. 

At Beachville distributing station the line entrance structure was rebuilt 
and the line switching revised so that now two circuits enter the station. 

The reinforcement of railway and telephone line crossings has been 
continued. 

GEORGIAN BAY SYSTEM 

Eugenia District 

Between Crombie junction and Orangeville distributing station 16.35 miles 
of single-circuit, wood-pole line with telephone circuit were constructed. This 
new line replaces the old which had become inadequate. 

Severn and Wasdells Districts 

Sixteen railway and telephone line crossings were reinforced in the Severn 
and Wasdells Districts. 

Work in these districts was confined to the reinforcement of crossings in 
compliance with regulations of the Board of Railway Commissioners. 

EASTERN ONTARIO SYSTEM 

Between Dominionville junction and Maxville distributing station, 5.17 
miles, the existing line which was originally built for 44,000 volts, but operated 
at 4,000 volts was connected to the 44,000-volt circuit at Dominionville junction. 

THUNDER BAY SYSTEM 

Construction was completed of 48 miles of 33, 000-volt, wood-pole line 
between Cameron Falls transformer station and the Beardmore mine. This 
line is single-circuit with conductors of No. 4 solid copper. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



109 



*-7K 



v .y t „-V* 



3* t_ 



^ 




HYDRO 220,000-VOLT TRANSMISSION LINES 
Transposition towers on the Beauharnois-Chats Falls line 




Semi-anchor tower showing loop without 
suspension insulator 



HYDRO 220,000-VOLT TRANSMISSION LINES 
BEAUHARNOIS-CHATS FALLS 

Suspension tower with ten-foot extension 



1J0 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

TELEPHONE LINES— ALL SYSTEMS 

The telephone system of the recently purchased D. P. & T. Co. was 
co-ordinated with that of the Niagara system. Approximately 17.5 miles of 
single-circuit were erected to interconnect the two systems in the vicinity of 
Hamilton, Decew Falls and St. Catharines. 

In the vicinity of Effingham 1.40 miles of four-circuit, high-tension, telephone 
line were diverted to a shorter route which eliminated extensive yearly tree 
trimming. 

DISTRIBUTION LINES AND SYSTEMS 

In Appendix III is shown in tabular form the routine work carried on 
during the year ended October 31, 1933, by the Distribution section of the 
Electrical Engineering department. 

Below is given a brief summary of some of the work undertaken by this 
section in addition to the engineering activities required in connection with the 
construction of new lines: 

It is now twelve years since the first rural power districts were established. 
While it is known that wood-pole lines in general have a life greater than this 
period, in certain soils the decay in wood poles is very rapid. In addition, due 
to growth in load and distance of transmission, the conductor sizes originally 
installed become inadequate. 

It should be noted also that before the present scheme of rural power districts 
was originated, there were lines built to serve rural consumers by the Commission 
and by the municipalities. These lines have practically all been incorporated 
into the rural power districts. The time has now come when it is advantageous 
to make a check of the physical condition of these old lines and also the adequacy 
of the existing conductors to give satisfactory service with the present loads. 

During the past year, the poles on some 75 miles of rural and distribution 
feeder lines have been tested and recommendations made for the replacement 
of about twenty per cent of these poles. In addition, voltage and load tests 
were made in six rural power districts and recommendations made for the 
improvement of conditions in these districts. 

One item of improvement has been the installation of automatic booster 
transformers at four locations. These automatic booster transformers are a 
development of the past year. 

While endeavouring to locate trouble on a privately owned underground 
cable, a new method for finding faults on underground cable was developed. 
This method was successfully used where other common methods of cable 
testing failed owing to the nature of the fault. A current was passed through 
the cable which was sufficient to warm the lead sheath which is used as a return 
conductor. By exposing the cable at intervals and feeling the lead sheath with 
the hand, the point of fault can be located by the lower temperature of the 
sheath past the fault. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



111 



RURAL POWER DISTRICTS 

GROWTH IN CAPITAL INVESTMENT -MILES OF LINE -NUMBER OF CONSUMERS 


YEAR 1921 1922 1923 1924 1925 1926 1927 1928 1929 1930 1931 1932 1933 1934 


DOLLARS 


CAPITAL INVESTMENT 


26,000,000 

24.000,000 

22,000,000 

20,000,000 

18.000,000 

16. OOO, OOO 

14.000.000 

I2.000.000 

IO. OOO. OOO 

8,000,000 

6.000.000 

4.000,000 

2.000,000 

o 




























































































































































































/' 
























/ 


























/ 


























^y 


f 




































































































■ 




























MILES 


MILES OF PRIMARY LINE CONSTRUCTED 


13, OOO 

12 OOO 

1 1. ooo 

10,000 

9,000 

8.0 

7,000 

6 OOO 

5. OOO 

4.000 

3,000 

2, OOO 

1. OOO 

o 




























































































































































































/' 














































































































































































































NUMBER 


NUMBER OF CONSUMERS 


6 5,0 OO 

6 O. O O O 

5 5, O O O 

5 O, O O O 

4 5, OOO 

40,000 

3 5, OOO 

3 0, OOO 

25, OOO 

20,000 

1 5, OOO 

IO, OOO 

5. OOO 
O 














































































y 






































































































































/ 


























/ 


























/ 


/ 












































































,/ 




















































VEAR 1921 1922 1923 1924 1925 1926 1927 1928 1929 1930 1931 1932 1933 1934 



112 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

The work of ground connection improvement has been continued during 
the past year. To date, tests have been made on the resistance of some 23,000 
grounds in 160 rural power districts. Specifications for the necessary improve- 
ment have been issued in 68 rural power districts in which there are approximately 
13,000 ground connections. In the above 160 rural power districts, about 
14,000 ground connections now meet the standard of 25 ohms or less. 

Weekly tests were made during the year on the resistance of the ground 
terminals at the four test stations installed near Toronto. It is proposed to 
carry on these tests during the winter of 1933-34 in order to obtain more complete 
records of the effect of frost on the ground terminal resistance. 

The results of the past years tests are now being analyzed. Upon completion 
of this analysis, a report of the results obtained will be issued. 



1934 HYDRO-ELECTRIC POWER COMMISSION 113 



SECTION VII 



TESTING— RESEARCH— INSPECTION 



The Testing and Inspection department has three main divisions — the 
Testing and Research laboratories, the Approvals laboratory, and the Electrical 
Inspection division. 

The division of the department known as the Testing and Research labora- 
tories comprises the Electrical laboratory, Engineering Materials laboratory, 
Chemical laboratory, Illumination laboratory, and the Photographic and 
Blueprint b ranches. This division supplies a testing, research and materials- 
inspection service to the other departments of the Commission and to the Muni- 
cipalities embraced in the Commission's operations. Its staff is composed of 
engineers, chemists and laboratory assistants who carry out their duties in the 
laboratories or in the field, as expediency or necessity may dictate. The 
Approvals laboratory is charged with the duty of administering the rules and 
regulations of the Commission governing electrical equipment. It is composed 
of a staff of laboratory engineers and factory inspectors; the former are engaged 
almost entirely in making laboratory tests and the latter in making inspections 
in the factories and in the field. The Electrical Inspection division is responsible 
for the administration of the Rules and Regulations of the Commission governing 
electrical installations. It is organized in districts covering the entire Province, 
in each of which one or more inspectors are stationed. The work of this division 
involves inspection, but this is quite different to the inspection carried on by the 
Testing and Research laboratories. The latter inspects materials and equipment 
which the Commission purchases for its own use while the former is charged 
with the duty of inspecting wiring installations in houses, offices, etc. and indus- 
trial installations in order to determine whether or not such installations contain 
a fire or a shock hazard. 

An event of importance in the year's operations was the formation of a 
Research committee in the Commission. The objects of this committee are: 
to correlate the investigational work of all departments, to discover and develop 
research talent in the Commission, to encourage the staff to submit ideas which 
may be developed for the benefit of the Commission and to guide research work 
in the Commission. The main Research committee consists of five department 
heads. Sub-committees are appointed to undertake specific research under the 
direction of the main committee. Nine projects are now active and encouraging 
progress has been made. Reference is made below to several of these projects. 



H4 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

TESTING AND RESEARCH LABORATORIES 

Statistical and Routine Work 

During the year, 40,784 tests of all classes were made in this division of 
the department. Of this total the Electrical laboratory made 15,734 tests, the 
Chemical laboratory 1,195, the Structural Materials laboratory 4,097, and the 
Photometric laboratory 19,758. The Blueprint branch completed 3,778 orders 
and made 48,171 prints having a total area of 121,679 square feet, and the 
Photographic branch completed 551 orders covering all phases of dark room, 
studio and field photography. These statistics cover testing to assure the 
standard of quality of items such as insulating oil, transmission line hardware, 
rubber gloves, oils and paints, wire and cable, concrete materials and luminous 
lighting devices as well as special tests involved in miscellaneous investigations 
and research. 

Although this particular phase of the laboratory activities does not change 
materially from year to year, the work is continually becoming more diversified 
and the laboratory is called upon to develop new methods and equipment for 
routine or special testing. An example of this is the new section recently estab- 
lished for conducting physical and chemical tests on insulated wire conductors 
and electrical conduit and tubing. 

Materials and Equipment Inspection Work 

The volume of general inspection work was considerably reduced this year 
owing to the continued depression in the construction activities of the Com- 
mission. 

Transmission Line Materials 

The routine inspection of transmission line materials was of the same general 
character as in previous years. All articles such as bolts, cross-arms, pins, 
splices, connectors, brackets, galvanized steel wire, copper and aluminum con- 
ductors and tower-line steel are subjected to rigid inspection either at the 
laboratory or in the manufacturers' shops. Faulty materials are thus eliminated 
and hazards to human life as well as service interruptions due to line failures 
are minimized. 

Equipment 

The principal items inspected during the period covered by this report were 
44 transformers of total capacity 221,805 kv-a and equipment required in the 
construction of seven electric steam generators having a total capacity of 130,000 
kw. During the fabrication of boiler steel for these generators a resident 
inspector was stationed at the plant, and witness tests were made on the assembled 
units before final acceptance was granted. Particular attention was also given 
to the welding of equipment for these installations. 

Preliminary work has been done on the inspection of equipment required to 
complete the Beauharnois contract. This will include the inspection of 
turbines, generators, governors, circuit breakers and transformers used to supply 
power to the Commission. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



15 




FIELD INSPECTION OF CONCRETE STRUCTURES 

Where conditions warrant, affected areas are outlined on the structure and photographed so 
that the rate of deterioration may be followed annually 

Concrete 

Inspection of the Commission's concrete structures as a means of detecting 
incipient deterioration has been continued. These inspections also afford an 
opportunity for the laboratory staff to observe the durability of various building 
materials in service and they assist in making recommendations as to the most 
suitable materials for the Commission's use. Inspections of this character 
during the year included eight plants in the Georgian Bay district, three plants 
in the Nipissing district, three plants in the Sudbury district, the canal walls at 
Queenston, the generating station and main dam at Eugenia, and the two plants 
on the Nipigon river. 

Although no major concrete construction has been carried out during the 
year, the inspection staff has assisted in making recommendations as to materials 
and mixtures for repair work and minor jobs, and has also compiled detailed 
records on the recently completed construction at Chats Falls and Abitibi Canyon. 



Research 

Mew Methods and Materials 

An important function of the testing and research division is to investigate 
the merits of new methods or materials and to report upon their usefulness or 
suitability in the Commission's maintenance and construction work. Items of 
this nature investigated during the year include cork insulations for preventing 
condensation on pipes; special devices for transmission line construction; paints 
for specialized purposes; spray equipment for creosoting poles; roofing materials 
for powerhouse use; heaters, thermostats and boiler lagging for domestic hot- 
water service; hardware for low- voltage lines, and insulating cements for electric 
steam generators. 



H6 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Investigation of Troubles 

The laboratories are frequently requested to investigate troubles which 
occur in operation and to report upon remedial measures which will prevent 
their reoccurrence. The following are typical examples of this type of service: 

Recommendations were made for treating cooling-pond water to 
prevent the formation of pipe scale. 

A metallurgical examination of a broken tower member revealed that 
segregation in the steel had caused the failure. 

Defective turbine runner bolts at Queenston. Microscopic examination 
revealed segregation of the metal and the replacement of these bolts was 
advised. 

Defective set screws from bearings at Queenston. Hardness and 
brittleness had caused failure through impact. Properly heat-treated set 
screws were recommended. 

Galvanizing which had turned black in service. This investigation is 
still in progress. 

Ground wire and dead-end clamps replaced in the field after several 
years' service were examined to determine any condition which would assist 
in making these replacements less frequent. 

Investigations Leading to Improvements in Methods or Materials 

The following problems have received attention during the year: 

Comparative tests on bare welding rod and covered rod. In all cases 
the covered rod was found to be superior. 

Investigation of the physical characteristics of aluminum strands in 
steel-reinforced aluminum conductors, particularly in regard to their bending 
qualities. The tests showed lack of uniformity in this respect. 

Study of a special line fault indicator. Sufficient time has not elapsed 
to warrant comment upon its merits. 

Development of an electrical stress-strain instrument for recording 
vibration in transmission line conductors. This promises to be a very 
useful piece of apparatus. 

Treatment of concrete walls where moisture presents a serious obstacle 
to painting. Several treatments have been investigated. 

Plastic insulating cement for covering joints in large electrical con- 
ductors. A satisfactory cement was found. 

Selection of a suitable cement filler for slate panels. 

Development of a new method of stubbing wood poles to prevent 
rotting at the ground line. Assistance was given our engineers at the 
laboratory and in the field. 

Water heating installations for domestic hot-water service. Many 
special tests were made to investigate the merits of equipment and types of 
assembly. A large amount of valuable practical data has been obtained 
and considerable assistance was afforded the manufacturers in developing 
suitable equipment. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



117 




APPARATUS FOR MEASURING THE GLOSS OF PAINTS 
Illumination Laboratory 



Treatment of Wood Poles 

The extent of the Commission's rural transmission lines has warranted a 
thorough investigation as to the efficiency of various kinds of preservative 
treatments. Considerable progress has been made in the study of this problem. 
Annual inspections of the Barrie test bed are being made and the installation of a 
second test bed near Donlands has been completed. Twenty-four soils from the 
Niagara district were tested, and over 400 poles from various localities were 
inspected and recorded for future study. A special device for creosoting poles 
already in service was investigated, and data pertaining to the history of certain 
selected pole lines were studied. 

Paint 

The testing and inspection of paint is one of the most valuable services 
rendered by the Chemical laboratory. This laboratory not only makes routine 
tests on paints regularly purchased by the Commission, but is constantly investi- 
gating the merits of new products and making recommendations where paints 
for special purposes are requested. It continues to co-operate in making 
laboratory tests and field inspections of tower line painting. This service has 
resulted in a substantial saving in maintenance charges. 

Recent developments in paint testing include : microscopic examination of 
specimens to detect initial failure and photometric measurements for gloss, 
where this feature is of importance. 



H8 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Concrete 

Concrete problems investigated during the year have included : 

Comparative tests on standard silica sands for cement testing. These 
tests were made in co-operation with the Canadian Engineering Standards 
Association with a view to adopting a Canadian sand if it proved satisfactory. 

Tests on standard aggregates for major concrete investigations. These 
tests were necessary as the materials formerly used as standard are no 
longer available. New materials were selected and tests were made to 
correlate our porportioning data. 

The grouting of joints which have given trouble in our existing concrete 
structures. Cement and asphalt materials were investigated and recom- 
mendations were made for the repair work at Nipigon. 

The study of problems relating to winter concreting. Placing of 
concrete during freezing weather presents many specific problems worthy 
of special consideration. An investigation is now in progress to study the 
thermal characteristics of concrete and concrete aggregates, the capacity 
of heating plant necessary for given temperature conditions, the heat 
generated by chemical reactions in freshly-set concrete and the curing 
temperatures necessary to provide economical yet adequate curing protection. 

The use of crushed limestone or granite as a substitute for natural 
sands. Proportioning tests for this study are now being made and over 
500 cylinders out of a total of 790 have been completed. 

Preliminary work done last year on an analysis of the variations in 
concrete strength tests has been continued. A comprehensive survey of 
Hydro and foreign field data was made to assist in revising the present 
concrete strength classifications. 

The resurfacing and patching of deteriorated concrete. Field tests 
have been made using various treatments on sidewalks. 

Typical defects which occur due to faulty design or construction have 
been photographed for the information of our engineers. 

Insulating Oils 

A major investigation is now being made to determine the feasibility of 
reconditioning insulating oil in large quantities. Apparatus of sufficient capacity 
to reclaim oil on a modified commercial basis has been assembled at the laboratory 
and the results of tests have been very encouraging. Some mechanical difficulties 
were experienced, but it is expected that satisfactory field equipment will be 
developed for restoring deteriorated oil to many additional years of service. 

Other studies in respect to insulating oil have been the investigation of 

operating temperatures as they affect the rate of deterioration, a survey to 

determine the condition of insulating oils in service and an investigation to 
establish a more sensitive test for sludge determination. 

Radio Interference 

The laboratories continue to co-operate with the Dominion Department of 
Marine in efforts to eliminate radio interference caused by apparatus on electrical 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



119 




ENDURANCE TEST ON THERMOSTATS 
Approvals Laboratory 



systems. The chief sources of this trouble are transformers, lightning arresters, 
fused outlets, insulators and some types of line hardware. Power companies 
are giving an increasing amount of attention to this matter. 

Oscillographic Studies 

Special tests on a rather extensive scale have been made using oscillograph 
elements where the time involved was of short duration. These instruments 
are particularly flexible and they may be used to record any mechanical quantity 
which may be duplicated by its electrical equivalent. 



Vibration of Transmission Line Conductors 

During the year the facilities of the laboratory were involved to a greater 
extent than heretofore in the study of vibrations in transmission line conductors. 
Several methods of attacking this problem have been investigated, and special 
electrical apparatus for measuring the vibrations has been developed. Very 
satisfactory progress has been made and it is expected that these studies will be 
continued. 



20 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 




LABORATORY FOR TESTING INSULATED WIRE CONDUCTORS 

A low-temperature refrigerator is shown at the left, the tension and recovery machine in the 
centre foreground and the cord endurance tester in the centre background 



Communication 

Communication problems are continuous in character but new aspects are 
constantly presenting themselves, particularly those in respect to carrier wave. 
The merits of several new systems have been studied. 

Industrial Research 

Assistance has been given in co-operation with the Department of Industrial 
Research, University of Toronto, in problems relating to resuscitation from 
electric shock and the prevention of silicosis. A member of the laboratory staff 
has been assigned to assist in the development and control of electrical apparatus 
used in the investigation of these important humanitarian problems. 



Miscellaneous 



New Equipment 



The only new equipment added during the year was that required in the 
establishment of a new section for testing insulated wire conductors and electrical 
tubing and conduit. As far as possible the equipment already in the laboratory 
was adapted to the new work, and only such apparatus as could not be assembled 
in our own shops was purchased. New equipment purchased for this work 
includes an electric refrigerator capable of attaining a temperature of -22° Fahr. 
and a Pyrofax gas machine for conducting flame tests. Both of these items may 
be used for a multiplicity of purposes in general laboratory work. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



21 




BRAKE TESTS ON SMALL MOTORS 
Approvals Laboratory 




TEMPERATURE AND OVERLOAD TESTS ON FUSES 
Approvals Laboratory 



L22 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

It was also necessary to purchase or construct for use in the laboratory 
several machines for physical testing of rubber and other insulating materials. 
These included a special refrigerator, machines for buffing rubber and stretching 
wire, impact testing, testing tensile strength of armoured cable and other cable, 
tightness of armour, abrasion of insulation and endurance of heater cords. It 
was also necessary to purchase a considerable number of small tools, micrometers, 
balances, gauges, dies, thermometers, etc. for bench work on these materials. 

To take care of life tests on thermostatically-operated controls for refrigera- 
tors and water heaters a special set-up was devised so that streams of hot and 
cold air alternately could be passed over the device at varying rates. Several 
new jigs were constructed for switch and socket tests, together with a device for 
applying heat so that heater switches could be operated at normal temperature. 
A 12-point pyrometer for measuring temperatures by means of thermocouples 
on automatic irons, toasters, percolators, etc. was adapted for use in the investi- 
gation of these appliances. 

A reactor coil was designed and constructed to furnish a load for testing 
switches for the control of single-phase motors. With this coil it is possible to 
obtain loads equivalent to locked-rotor loads of motors in capacities from 1/6 to 
2 h.p. at 115 volts and from 1 to 5 h.p. at 230 volts. 

Standardization 

The standardization activities of the department have on the whole been 
maintained at approximately the same level as last year. The preparation of 
specifications under Part II of the Canadian Electrical Code has been pressed 
vigorously forward, as noted in the report of the Approvals laboratory. The 
benefits of this work both to the Approvals laboratory and the manufacturers 
are continually evident. 

As mentioned in the last report, the Approvals laboratory on January 1, 1933, 
undertook the inspection of wire, cable, conduit and other items formerly under 
the inspection service of Underwriters' Laboratories. This work is carried on 
in co-operation with the Canadian manufacturers and the Canadian Engineering 
Standards Association under the standards of the Canadian Electrical Code. 

Lighting Service 

This service is provided for the use of the municipalities and their customers. 
During the year twelve reports were submitted in response to requests for 
lighting plans. 

Lamps 

The Photometric laboratory continues to conduct tests on and to make 
inspections of all Hydro lamps sold throughout the Province. Samples for 
life tests are selected from each batch of lamps manufactured for the Commission. 
The tests of these reveal the inherent quality of the lamps and serve to show 
whether or not they comply with the requirements of the Commission's specifica- 
tions. The accumulated information also furnishes a basis for improvements 
in efficiency as experience dictates. 



1934 HYDRO-ELECTRIC POWER COMMISSION [23 

APPROVALS LABORATORY 

Statistical 

The following table contains a summary of the testing and inspection work 
of the Approvals laboratory for the past two years: 

1932 1933 

Applications for approval 660 743 

Special approval tests, etc 178 237 

Listing 52 67 

Factory inspection reports 3,039 3,328 

Labels sold— (16 types) 696,100 621,723 

Conduit 446,000 

Wire, cord, etc 334,000 

Applications for approval : 

Motor-driven appliances 222 

Electrically-heated appliances 168 

Wiring devices 125 

Lighting devices . . . 106 

Industrial control and transformers 43 

Miscellaneous 43 

Wire and cable. 19 

Radio and sound 17 



Summary of Work 



Specifications 



Specifications in process by Canadian Engineering Standards 

Association, November 1, 1932 15 

Specifications printed since November 1, 1932 5 

Specifications advanced to final C.E.S.A. form 4 

Specifications begun during year 10 

(Some advanced to C.E.S.A. draft form and others still in 
laboratory draft.) 

Meetings of C.E.S.A. Specification Panel attended 15 

Average attendance of laboratory engineers 3.5 

Other meetings attended relating to Approvals work 3 

One engineer is devoting his whole time to specifications. Two others are 
giving part time and several others are consulted as required in order to insure 
that all requirements are properly covered by any draft. 

In addition to this work some standardization work has been done in con- 
nection with the marking of plug fuses and of mercury contact switches. Several 
bulletins were also issued referring to appliance plugs, use of flexible cords, 
cartridge enclosed fuses, and insulated wires and cables. By arrangement with 
Canadian Engineering Standards Association these bulletins were circulated 
by that association to manufacturers and others concerned. 



24 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 




ENDURANCE TEST ON THREE-HEAT RANGE SWITCHES 

This test is being made at constant temperature of 100 deg. C. 
Approvals Laboratory 



The Safety Code for elevator equipment proposed by the Canadian Engineer- 
ing Standards Association was reviewed and an appendix covering electrical 
features for inclusion in this code was compiled. 

Other specifications received through the Canadian Engineering Standards 
Association from the British Standards Institution and the Australian Standardiz- 
ation Association have also been reviewed and comments forwarded. 

Label Sales 



Commenting on the summary of labels sold, as compared with the previous 
year, there is a drop of approximately 75,000 or about 11 per cent. This 
loss of revenue was more than made up by the sale of labels for conduit, fixtures, 
insulated wire and cord, heater cord, armoured and non-metallic sheathed cable, 
flexible steel conduit and non-metallic tubing. The continued general depression 
in the building trades however kept the demand for this label service to a low 
point as it did not come up to the estimate. 

To handle the inspection required by an increasing number of label users 
in the district surrounding Montreal, it was found necessary to open a branch 



1934 HYDRO-ELECTRIC POWER COMMISSION [25 

office in Montreal where laboratory specifications and other information could 
be available as well as labels. This arrangement has worked out very well. 

In the Western Provinces, the business depression has probably been more 
acutely felt by manufacturers with the result that the falling off in demand for 
label service has been more pronounced than in Ontario and Quebec. 

A revised list of approved electrical equipment will be issued early in 1934. 



Field Sales Control 

During the year twenty-two offenders were brought to Police Court for 
breach of Rule 103 and many more were served, or about to be served, with 
summons but further action was dropped when compliance with the Regulations 
was forthcoming. Of the above number six were fined. 

An attempt was made by one concern to bring in substandard Christmas 
tree sets and incandescent lamps. Much time was taken up and several court 
cases resulted both in Toronto and surrounding towns before the further distri- 
bution of these sets was checked. The use of assumed names by the offenders 
made it difficult to cope with this class of offender. 



ELECTRICAL INSPECTION DEPARTMENT 

The Electrical Inspection department of the Hydro-Electric Power Com- 
mission has now been in operation for a period of eighteen years. It was formed, 
in the latter part of 1915, to supervise the carrying out of the Rules and Regula- 
tions governing electrical installations in all municipalities of the Province of 
Ontario. It functions for the Provincial Government under the direction of 
the Hydro- Electric Power Commission. 

While the work of the Department varies but little from year to year, the 
volume handled is governed, to a large extent, by the amount of new building 
construction carried on throughout the Province. The value of this has shown 
a steady decline from $116,203,200 in 1930 to $26,292,000 in 1933. 

There are reasons for believing that the bottom of the depression has been 
reached, so far as building construction statistics, covering a period of years, 
would indicate. The number of paid applications, for inspection, received in 
1933, amounted to 75,054, a decrease of 1,117 or 1.47 per cent from 1932. 

The small decrease in the number of permits issued does not however accord 
with the building construction situation, outlined above. The number of 
permits was maintained at a higher level as a result of the Commission's water 
heater campaign. If this field of work had not been created, the number of 
permits issued would have fallen off by approximately 15 per cent. 

In all, 137,760 inspections were made, a decrease of 16,135 or 12 per cent 
from 1932. 

The accompanying graph shows the monthly trend of permits issued, 
inspections made and the cost of building construction in Ontario for the period 
1930 to 1933. 



126 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NUMBER OF «. VALUE OF 

INSPECTIONS MADE BUILDING 

PERMITS ISSUED CONTRACTS LET 

isIUi5l§s§alisinii§S5§8lislSi8i§55i8lssIliliia5§§|jSllIiisSsi: 



30.000 



25.000 




$15,000,000 



$10,000,000 



$ 5,000,000 



1930 



1931 



1932 



1933 



NOTE— Curve A = No. of inspections; Curve B = No. of permits issued 
Curve C = Value of building contracts 



Fires 



Of the numerous fires reported to the Department as having been caused 
by defective electric wiring, investigation has definitely placed the causes of 
31 as due to defective wiring. This number is an increase of 11 over last year. 
The fires are classified, as to origin, below: 



Armoured cable 4 

Wires overfused 5 

Heaters (improperly used) 3 

Defective joints 2 

Short circuits 5 

Lamp in barn, covered with chaff, 

as a result of threshing operations 1 



Flexible cord 6 

Service conduit blowout 1 

Iron left on 1 

Motors 3 

Total 31 



1934 HYDRO-ELECTRIC POWER COMMISSION [27 

Electrocution 

During each year, a number of instances of electrocution are reported, in 
the- newspapers, throughout the Province. Most of these are brought about 
by persons coming into contact with high-voltage wiring and equipment which 
is not under the jurisdiction of the Inspection Department. 

Four fatal accidents occurred, within the past fiscal year, through equipment 
under the jurisdiction of this Department. The individual causes are cited 
below : 

Man electrocuted by coming into contact with an amusement device, 
on which an intermittent ground existed. Voltage of circuit, 110. 

Man electrocuted while making alterations to a heater connection; 
neglected to pull switch. Voltage of circuit, 550. 

Man electrocuted while working with an electric jack which was not 
grounded. Voltage of circuit, 550. 

Man electrocuted while painting pipe framework around switching 
equipment. Voltage of circuit, 2,200. 

Two cows and one horse were also electrocuted. High resistance 
grounds were the cause in each instance. 

Infractions of Regulations 

Forty-two persons and companies were prosecuted for various infractions of 
the Rules and Regulations. Fines amounting to $480 and a number of suspended 
sentences were imposed. 

The routine work of inspecting the older and more obsolete type of installa- 
tion has been carried on as in previous years. Owing to present conditions, more 
time and effort is required to influence the consumer to have the installation 
brought up to a reasonable standard of safety than was formerly the case. The 
Department has recognized the hardships which might be imposed, in this 
connection, and has only taken action where life and fire hazard exist. In all, 
2,603 installations were brought up to a reasonable safe condition at an approxi- 
mate cost of $138,848. 

Artificial Grounds 

This year, 2,222 artificial grounds were tested as compared with 3,824 last 
year. The readings obtained give the Department a knowledge of the ground 
protection on each installation before the supply lines are connected. This 
information, along with other data, is turned over to the Engineering department, 
for study, with a view to improving upon the types of artificial grounds now in use. 



128 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 



SECTION VIII 

ELECTRIC RAILWAYS 

THE SANDWICH, WINDSOR AND AMHERSTBURG 
RAILWAY COMPANY 

Operation 

In 1933 the gross earnings were $492,795 as compared with $568,452 in 
1932, a decrease of $75,657. The 1933 operating expenses were $498,134 as 
compared with $564,692 in 1932, a decrease of $66,558. There was an operating 
deficit of $5,340 as compared with an operating net of $3,759 in 1932. 

The adjustment of the 1932 power bill was made too late to be included in 
the 1932 report and the amount — $4,872 has been credited to 1933 operating 
expenses. Similarly, the 1933 adjustment has not been made at this writing. 

Industrial conditions in the Border Cities show little or no change for the 
better and the earnings of the Railway decreased 13 per cent while operating 
expenses have been reduced 11.7 per cent. 

The accompanying chart indicates the record of the Railway for the past 
five years. 

The mileage operated by the various types of cars during the year is as 
follows: — double truck, air brake, two-man cars 2,823 car-miles; interurban 
cars, 438,297 car-miles; single truck safety cars, 569,528 car-miles; double truck 
safety cars, 1,311,334 car-miles; express cars 10,944 car-miles; service cars, 
12,268 car-miles; total 2,345,194 car-miles. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



129 



SANDWICH, WINDSOR AND AMHERSTBURG RAILWAY 
OPERATING STATISTICS 





GROSS REVENUE 


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NET OPERATING REVENUE EXCLUDING TAXES 


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1933 



130 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

SANDWICH, WINDSOR AND AMHERSTBURG RAILWAY 

Operating Statistics, 1933 

Route-miles: — 

City 24 . 81 

Amherstburg interurban 13 . 54 

Tecumseh interurban 5 . 34 

Total route-miles 43 . 69 



Passenger and freight car-miles operated 2,332,926 

Passenger and freight car-hours operated 237,426 

Passengers carried 8,576,698 

Percentage of transfer passengers to revenue passengers 21 . 15 % 

Passenger cars operated 58 

Passengers carried per route-mile 196,308 

Passengers carried per car-mile 3.7 

Passengers carried per car-hour 36.4 

Average mileage per car operated 40,031 

Average passengers per car operated 147,874 

Freight tonnage carried 1,616 

Accidents 315, of which 214 were automobile accidents. 

Accidents per 100,000 car-miles: 12.698. 



GUELPH DISTRICT RAILWAY 

Operation 

The operating revenue for the Guelph District Railways for 1933 was 
$57,455 as compared with $65,595 in 1932. The operating expenses for the year 
1933 were $69,806 as compared with $73,380 in 1932. The net operating shortage 
was $12,351, as compared with $7,784 in 1932. The interest and debenture 
payments were $25,468 as compared with $25,588 in 1932. Sinking Fund 
requirements were $3,15-9 as compared with $3,159 in 1932. Nothing was set 
aside for renewals. The deficit for 1933 was $41,332 as compared with $36,885 
in 1932. 

Included in the above deficit is $8,351, which had been set aside for 
amortizing the original value of the Railway previous to the transfer of this 
road to the Hydro-Electric Power Commission; and also an interest charge of 
$3,349. 

The freight earnings for the year 1933 were $8,931 as compared with $10,506 . 
Passenger earnings were $47,921 in 1933 as compared with $54,373 in 1932. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



131 



GUELPH DISTRICT RAILWAYS— OPERATING STATISTICS 



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OCT 
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FEB 

APR 

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JULY 

AUG 

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DEC 

JAN 

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1930 



1931 



1932 



1933 



Ybl TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

GUELPH DISTRICT RAILWAY 

Operating Statistics, 1933 

Route-miles: — 

Trolley 6.41 

Bus 5 .99 

Total route-miles 1 2 . 40 

Track-m iles 9.06 

Passenger cars operated 7 

Buses operated 4 

Passenger car-miles operated 221,185 

Bus-miles operated 91,419 

Freight-locomotive-miles 9,908 

Passenger car-hours operated 27,619 

Passenger bus-hours operated 13,037 

Revenue passengers carried 835,867 

Transfer passengers carried 226,996 

Free passengers carried 3,402 

Total passengers carried 1,066,285 

Percentage of transfer passengers to revenue passengers 27 . 1 

Freight motor cars operated 1 

Freight motor-hours operated 2,141 

Total passenger freight and service car-miles operated 332,536 

Accidents: — 17 of which 11 were due to automobiles. 

Accidents per 100,000 car-miles— 1927, 8.24; 1928, 4.25; 1929, 12.3; 1930, 7.2; 1931, 4.45; 
1932, 5.95; 1933, 5.1. 



934 HYDRO-ELECTRIC POWER COMMISSION 133 



SECTION IX 



FINANCIAL STATEMENTS 



Relating to Properties Operated by The Hydro -Electric Power 
Commission on Behalf of Municipalities 

The following explanatory statement is submitted with a view to affording 
a satisfactory understanding of the manner in which the various operations of 
the Hydro-Electric Power Commission of Ontario are conducted and financed 
and thus contributing to the interest of those concerned either directly or 
indirectly with the Work of the Commission. 

The "Hydro" electrical undertaking of Ontario is an organization of a large 
number of partner municipalities co-ordinated into groups or systems for securing 
common action with respect to power supplies, through the medium of the 
Hydro-Electric Power Commission which under the Power Commission Act 
functions as their trustee. The undertaking as a whole, embracing all the 
operations from the provision of the power down to its final delivery to the 
ultimate consumer, involves two distinct phases of operations. 

The first phase of operations is the provision of the electrical power — either 
by generation or purchase — and its transformation, transmission and delivery 
in wholesale quantities to individual municipal utilities, to large industrial 
consumers, and to rural power districts. This phase of the operations is 
performed by the Hydro-Electric Power Commission of Ontario as trustee for 
the municipalities acting collectively in groups or "systems," and the financial 
statements relating to these collective activities of the municipalities are 
presented in this section of the Annual Report. 

The second phase of operations is the retail distribution of electrical energy 
to consumers within the limits of the areas served by the various municipal 
utilities and rural power districts. In the case of rural power districts, which 
usually embrace within their confines portions of more than one township, the 
Hydro-Electric Power Commission not only provides the power at wholesale, but 
also — on behalf of the respective individual townships — attends to all physical 
and financial operations connected with the distribution of energy at retail to 
the consumers within the rural power districts.* The financial statements 
relating to the rural power districts are also presented in this section of the 
report. In the case of cities, towns, many villages and certain thickly populated 
areas of townships, retail distribution of electrical energy provided by the 
Commission is in general conducted by individual local municipal utility com- 

*For further information respecting rural power districts consult latter portion of Section 
III in this Report. 



134 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

missions under the general supervision of the Hydro-Electric Power Commission 
of Ontario. The balance sheets, operating reports and statistical data relating 
to such individual electrical utilities are presented in Section X of this report. 

Having the foregoing distinctions respecting wholesale and retail electrical 
service in mind, the following brief notes will assist to an understanding of the 
economic structure and of the general plan of administration of the undertaking, 
and will make clearer the financial tables herein presented. The basic principle 
governing the financial operations of the undertaking is that electrical service 
be given by the Commission to the municipalities and by the municipalities to 
the ultimate consumers at cost. 

The charges for power supplied by the Commission to the various 
municipalities vary with the amounts of power used, the distances from the 
sources of supply and other factors. The entire capital cost of the various power 
developments and transmission systems is annually allocated to the connected 
municipalities and other wholesale power consumers, according to the relative 
use made of the lines and equipment. Each municipality assumes responsibility 
for that portion of property employed in providing and transmitting power for 
its use, together with such expenses — including the cost of purchased power if 
any — as are incidental to the provision and delivery of its wholesale power. The 
entire annual expenses — including appropriations for reserves — incurred by the 
Commission in the supply of power at wholesale are thus paid out of revenues 
collected in respect of such power, through the medium of power bills rendered 
by the Commission. The municipalities are billed at an estimated interim rate 
each month during the year and credit or debtit adjustment is made at the end of 
the year,* when the Commission's books are closed and the actual cost payable 
by each municipality for power received has been determined. 

Included in the municipality's remittance to the Commission for the 
wholesale cost of power — besides such direct expenses as those for operation 
and maintenance of plant, for administration, and for interest on capital — are 
sums required to build up reserves for sinking fund, for renewals, and for 
obsolescence and contingencies. The first-mentioned reserve is for the purpose 
of liquidating the capital liabilites; consequently, as capital obligations are 
discharged the plant will progressively be freed from interest expense. The 
other reserves are, respectively, being created to provide funds for the replacing 
or rebuilding of plant as it wears out; to enable the undertaking to replace 
existing equipment with improved equipment as it becomes available through 
advances in science and invention, and to meet unforeseen expenses which from 
time to time may arise. 

The ultimate source of all revenue to meet costs — whether for the larger 
operations of the Hydro-Electric Power Commission or for the smaller local 
operations of the municipalities — is, of course, the consumer. Out of the total 
revenue collected by each municipal utility from its consumers for service 
supplied, only an amount sufficient to pay the wholesale cost of power supplied 
by the Commission as outlined above is remitted to the Commission; the balance 
of municipal electrical revenue is retained to pay for the expense incurred by 
the local utility in distributing the electrical energy to its consumers. 

*The financial year for the Commission ends on October 31. The financial year for the 
municipal electric utilities, however, ends on December 31, and the municipal accounts are 
made up to this date, and so recorded in Section X. 



1934 HYDRO-ELECTRIC POWER COMMISSION [35 

The results obtained by the annual adjustments of the Commission's 
capital investment, operating expenses and fixed charges, as they affect individual 
municipalities are shown in the tables for the respective systems. For the purpose 
of financial statement, the various systems are treated as separate units and for 
each of them similar statements and details are presented. Many of the pages 
which follow, therefore, simply repeat for each system data similar to those 
which are presented for the first system dealt with in each division of the report, 
namely, the Niagara system. In order, therefore, to possess a ready grasp of all 
the figures presented in this and other similar reports of the Commission, all 
that is necessary is to have a true understanding of the financial procedure 
followed in connection with one system and with one municipal "Hydro" utility. 

The accounts of the Hydro-Electric Power Commission of Ontario are 
verified by auditors specially appointed by the Provincial Government. The 
accounts of the "Hydro" utility of each individual municipality are prepared 
according to approved and standard practice and are also duly audited. 

Tabular Data 

The first tabular statement given in Section IX is a general balance sheet 
exhibiting the assets and liabilities of the undertaking and relates to the properties 
constructed or otherwise acquired and being operated by the Commission as 
trustee for the municipalities of the various systems. 

The general balance sheet is followed by groups of statements relating in 
turn to each system of the Commission. These statements, for each system, 
are similar in character and include: — 

Operating Account for the year, showing, for the system as a whole, 
the various items of operating expense and fixed charges entering into the 
cost of power as defined by the Power Commission Act, and the revenues 
collected by the Commission from the partner municipalities and other 
consumers. 

Cost of Power statement, which shows the apportionment to each 
municipality or rural power district of the items of cost summarized in the 
Operating Account, as well as the apportionment of the capital expenditures 
listed in the balance sheet and the amount of power taken by each muni- 
cipality. It should be appreciated that the cost of power given in this table 
is the wholesale cost, — that is, the cost which the Commission receives for 
the power delivered from the main transformer stations serving the local 
utility or rural power district. In the case of rural power districts, the costs 
of power for the respective districts appear also in the "Rural Operating" 
statement, immediately following, as "Cost of power delivered"; in the case 
of municipal electrical utilities not directly administered by the Commission, 
the respective costs of power appear in Statement "B" of Section X as 
"Power purchased."* 

Rural Operating statement, which shows for each rural power district 
the various items of cost, and the revenues received, in connection with the 
distribution of electrical energy to consumers. 

Credit or Charge statement, which shows the adjustments made in 
order to bring the amounts paid by each municipal electric utility to the 
actual cost of service to that municipality. These credits and charges are 
taken up and given effect to in the municipal accounts of "Hydro" utilities 
before the operating records of each year are c losed . 
*Consult footnote on previous page. 



B6 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

Reserve for Renewals, which shows the provisions made for, the 

expenditures from, and the balances to the credit of, this fund. 

Reserve for Obsolescence and Contingencies, which gives similar 

information with respect to this reserve. 

Sinking Fund statement, which gives the accumulated total of the 

amounts paid by each municipality and rural power district as part of the 

cost of power together with its proportionate share of other sinking funds. 
Sinking Fund Reserve, which summarizes the provisions made with 

respect to this fund. 

All municipal "Hydro" utilities have current expenses to meet similar to 
the expenses of the Commission and have adopted the same financial procedure 
with respect to their operations. In other words, concurrently with the creation 
of funds to liquidate their debt to the Commission and to provide the necessary 
reserve to protect generating, transforming, and transmission systems, the 
municipalities are taking similar action with respect to their local "Hydro" 
utility systems. 

The balance sheets, operating reports and statistical data appearing in 
Section X, under the heading of "Municipal Accounts," relate to the operation 
of local distribution systems by individual municipalities which have contracted 
with the Commission for their supply of electrical energy. To this section there 
is an explanatory introduction to which the reader is specially referred. 

To illustrate further the foregoing explanatory comments, there is presented 
herewith a typical operating statement of an Ontario municipal electrical utility, 
covering its financial operations, both as a partner in a system of the Hydro- 
Electric Power Commission, and as administrator of its own local distribution 
system. 

FERTH "HYDRO" UTILITY 

A Typical Operating Statement for the year 1933 
Revenue 

Collected from Perth "Hydro" customers for year $61,537. 70 

Expenses 

A. — Incurred by the Hydro-Electric Power Commission on behalf 
of the municipality of Perth in connection with the supplying of 
its electrical energy. These data show — as determined by annual 
adjustment — what it costs the Commission to supply the municipality 
with its wholesale power. See "Cost of Power" statement, page 238, 
for the Town of Perth as follows: 

Cost (proportionate share) of power purchased for 
Eastern Ontario system, from generating plants not 
owned by Commission $8,855 . 40 

Cost (proportionate share) of operation and maintenance 
expense of Eastern Ontario generating plants, trans- 
former stations and transmission lines together with 
administrative expenses 7,227 . 15 

Interest, including exchange, on Perth's proportionate 
share of capital investment in generating plants, 
transformer stations and transmission lines 10,822.48 



1934 HYDRO-ELECTRIC POWER COMMISSION \37 

Renewal reserve (proportionate share) provided in 
respect of generating plants, transformer stations 
and transmission lines $2,968 . 15 

Obsolescence and contingencies reserve (proportionate 
share) provided in respect of generating plants, 
transformer stations and transmission lines 873.66 

Sinking Fund (proportionate share) provided in respect 
of generating plants, transformer stations and 
transmission lines 2,269 . 89 

Cost in excess of revenue from power sold to private 

companies* 5,005 . 70 



$38,022.43 



B. — Incurred by the municipality of Perth through its utility 
commission in connection with the sale of electrical energy to con- 
sumers. Consult the section dealing with the Municipal Accounts: 

Operation, maintenance and administrative expenses. . . . $8,648.87 

Interest on debenture debt, etc 2,880.45 

Sinking fund and principal payments on debentures 1,819.09 

Depreciation and other reserves 3,224. 00 



$16,572.41 
Total Expenses 

Charged against revenue from customers of the Perth System. . $54,594.84 



Net Surplus for the year $6,942 . 86 

The municipality of Perth, situated in the south eastern part of the 
Province, was connected to the Eastern Ontario system in February, 1919. 
With the close of the fourteenth year of operation, this utility's total assets are 
$220,342.86, liabilities $57,695.17, and reserves and surplus, $162,647.69, as 
shown in the municipalities' balance sheets, in Section X, Statement "A." 

By reference to this municipality's balance sheet, it will be noted that the 
Perth "Hydro" utility has created a sinking fund equity amounting to 
$34,151.00 in the Hydro-Electric Power Commission system. 

By reference to Statement "D" in Section X of this report it will be seen 
that under the low rate schedules prevailing throughout the Province, the rates 
in force in Perth have resulted in average costs] to the various classes of service 
as follows: Domestic service (with an average monthly consumption per 
consumer of 93 kilowatt-hours) 2.2 cents per kilowatt-hour; commercial light 
service 2.8 cents per kilowatt-hour. The actual rates in force are presented in 
Statement "E" and particulars of street lighting service are given in Statement 
"C" 

This represents the difference between the revenue received from private companies and 
other power customers operating under flat-rate contracts, and the result obtained by "costing" 
these loads on exactly the same basis as that used in determining "costs" in respect of municipal 
contracts, including sinking fund and other reserves. 

flf proper differentiation be made by those undertaking research, between the very different 
entities of rates on the one hand and the derived quantities of average costs or revenues on the 
other, a great deal of confusion and misrepresentation will be avoided. Consult introduction 
to Statement "D" of Section X. 



138 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

HYDRO-ELECTRIC POWER 

Detailed Statement of Assets 

POWER UNDER 
Assets 
Niagara System: 

Generating Plants: 

Queenston-Chippavva development $76,891,330. 14 

Ontario Power development, including water rights. . . . 22,035,794.89 

Toronto Power development, including water rights. . . . 11,522,054.50 

Chats Falls power development 6,167,756.08 

DeCew power development and steam plant, including 

water rights 11,824,138.13 

Transmission Lines: 

Right-of-way . 8,428,947 . 36 

Steel-tower and wood-pole lines 25,784,995 . 12 

Transformer Stations 35,257,130.56 

$197,912,146.78 

Distribution Lines: 

Rural power districts $6,440,310.91 

Rural lines 35,527 . 44 

Local distribution systems 422,618.53 

6,898,456.88 

$204,810,603.66 

Share capital of Hamilton Street Railway Company carried 

at a value of $3,000,000 . 00 

Cash advances to Hamilton Street Railway to cover capital 

expenditures and for working capital 250,837 . 27 

3,250,837.27 

Radial Railways in vicinity of Hamilton in process of liquidation — balance 

expected to be recovered 81,986 .56 

Balances owing under agreements covering 
sales of certain properties, plants and 
equipment: 

By City of Hamilton $1,812,500.00 

By City of Brantford 116,000.00 

By Canada Coach Lines, Limited. ... $525,000.00 

Accrued interest thereon 8,845 .82 

533,845.82 
Shares (1,000) of First Preferred stock of Canada Coach 

Lines, Limited— at par 100,000.00 

2,562,345.82 

Thunder Bay System: 

Nipigon generating plants $15,688,226.21 

Transmission lines 1,913,736.96 

Transformer stations 974,870.00 

$18,576,833.17 
Distribution lines: 

Rural power districts 53,939 .01 

18,630,772.18 

Carried forward $229,336,545.49 



1934 HYDRO-ELECTRIC POWER COMMISSION 139 

COMMISSION OF ONTARIO 

and Liabilities, October 31, 1933 

TAKINGS 

Liabilities 
To Province of Ontario: 

Cash advances for Niagara and other systems $204,973,166. 14 

Less: Repayment under provisions of Power Commission Act 17,008,616.73 

$187,964,549. 41 

Grant funds in the hands of the Commission to apply against 
rural power districts in course of construction or 
extension 40, 1 14 . 69 

Amount received from the Province for the purpose of making 
loans under provisions of the Rural Power District Loans 
Act $85,000.00 

Note: Loans made to October 31, 1933, $84,912.64. 

Less: Principal instalments on such loans collected and 

repaid to the Province 19,395 . 86 

65,604.14 

Debentures issued by the Commission and guaran- 
teed by the Province of Ontario: 

Four per cent debentures, due 1957, issued in 
purchase of Ontario Power Company of 

Niagara Falls $8,000,000.00 

Interest accrued thereon 80,000.00 

$8,080,000.00 

Six per cent debentures, due 1941, issued for 
the purpose of retiring the 1921 issue of the 
Ontario Power Company of Niagara Falls. $3, 200,000. 00 

Interest accrued thereon 67,856.16 

3,267,856.16 

Six per cent debentures, due 1940, issued in 
purchase of the Toronto Power Company 

Limited $413,200.00 

Interest accrued thereon 10,330.00 

423,530.00 

Six per cent, debentures, due 1940, issued in 
purchase of certain electrical power equip- 
ment of the Toronto and York Radial 

Railway $205,800.00 

Interest accrued thereon 5,145 .00 

210,945.00 

Five per cent debentures, due 1939, issued for 
the purpose of retiring the 1924 issue of 

the Toronto Power Company Limited $4,000,000.00 

Interest accrued thereon 75,000 .00 

4,075,000.00 

Four per cent debentures, due 1958, issued in 
purchase of distribution lines of Essex 

County $200,000 00 

Interest accrued thereon 3,333 .34 

203,333 . 34 

$16,260,664 . 50 

Carried forward $188,070,268. 24 



HO TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

HYDRO-ELECTRIC POWER 

Detailed Statement of Assets 

POWER UNDER 
Assets 

Brought forward $229,336,545.49 

Georgian Bay System: 

Generating plants $3,771,083 .28 

Transmission lines 2,602,025 .41 

Transformer stations 1,159,113 .39 

$7,532,222.08 

Distribution lines: 

Rural power districts $780,691 . 26 

Rural lines 2,807.43 

Local distribution systems 78,924.48 

862,423.17 
8,394,645.25 

Eastern Ontario System: 

Generating plants, including water rights $10,114,637.74 

Surveys and engineering re power sites: 

On St. Lawrence river $734,873 .31 

On Ottawa river 94,135.20 

829,008.51 

Properties purchased for power sites 52,533 .33 

Transmission lines 3,926,845 . 19 

Transformer stations 2,552,680.41 

Rural power districts $1,619,158.39 

Local distribution systems: 

Electric 108,573 .01 

Gas 26,534.67 

Rural lines 90,302 . 26 

Pulp Mill 52,559 .93 

1,897,128.26 



19,372,833.44 



Northern Ontario Properties — comprising the Nipissing, 
Wahnapitae, Abitibi-Sudbury and Patricia (Ear Falls) 
Districts as follows: 

Nipissing District: 

Generating plant $1,102,909.40 

Transmission lines 172,660.81 

Transformer stations 15,814 .00 

$1,291,384.21 

Rural power districts $19,254 . 45 

Local distribution systems 361,065 .83 

380,320.28 

Wahnapitae District: 

Properties, buildings, plant, equipment and water rights 

on Wahnapitae river $2,516,994.40 

Transmission lines 139,015 . 15 

Transformer stations 43,804 .00 

$2,699,813.55 
Local distribution systems 6,630 . 43 



1.671,704.49 



2,706,443.98 



Carried forward $261,482,172.65 



1934 HYDRO-ELECTRIC POWER COMMISSION 14] 

COMMISSION OF ONTARIO 

and Liabilities, October 31, 1933 

TAKINGS — Continued 

Liabilities 
Brought forward $16,260,664.50 $188,070,268.24 

Debentures issued by the Commission and guaranteed by the 
Province of Ontario — Continued. 

Four per cent debentures, due 1958, issued in 
purchase of distribution lines in vicinity of 

Thorold $100,000.00 

Interest accrued thereon 1,666.67 

101,666.67 

Four and three-quarter per cent debentures, 

due 1970, issued in part purchase of Under- 
takings and Companies from Dominion 
Power and Transmission Company, Limited 

as at January 1, 1930 $13,000,000.00 

Interest accrued thereon 206,397 . 00 

13,206,397.00 

Five per cent Debentures, due 1935, issued 

in part purchase of Undertakings and 
Companies from Dominion Power and 
Transmission Company, Limited, as at 

January 1, 1930 $8,000,000.00 

Interest accrued thereon 133,698 . 00 

8,133,698.00 

37,702,426.17 

Four and one-half per cent debentures, due 

1938, issued to retire Guaranteed Deben- 
ture Stock and other debentures $6,000,000.00 

Interest accrued thereon 67,500.00 

$6,067,500.00 

Twenty-year debentures maturing in 1952 and 

bearing interest at the rates of 33^% in 
first five years, 4% in next five years, 5% 
in last ten years, issued in purchase of 
bonds of Ontario Power Service Corpora- 
tion Limited, which bonds were in turn sur- 
rendered in the purchase of the properties 

and assets of that Company $17,626,950.00 

Interest accrued thereon 50,707 . 66 

17,677,657.66 

23,745,157.66 

Bonds and debenture stock assumed by the Commission and 

guaranteed by the Province of Ontario: 

First mortgage 5 % gold bonds, due 1943, of the 
Ontario Power Company of Niagara Falls: 

Amount assumed at date of purchase of Com- 
pany by Commission, August 1, 1917. . . .$9,834,000.00 
Less: Retired by the Commission 2,042,000.00 

$7,792,000.00 
Interest accrued thereon 97,400 .00 

$7,889,400.00 

First mortgage 5 % gold bonds, due 1945, of the 

Ontario Transmission Company, Limited: 
Amount assumed at date of purchase of Com- 
pany by Commission, August 1, 1917. . . .$1,772,000.00 
Less: Retired by the Commission 497,000.00 

$1,275,000.00 
Interest thereon payable November 1, 1933 31,875 .00 

1,306,875.00 

$9,196,275.00 

Carried forward $249,517,852.07 



42 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



Brought forward 



Assets 



HYDROELECTRIC POWER 
Detailed Statement of Assets 

POWER UNDER 
$261,482,172.65 



Northern Ontario Properties — Continued. 
Abitibi-Sudbury District: 

Abitibi Canyon generating plant (uncompleted) and 

adjacent lines $16,729,782 .45 

Hunta-Copper Cliff line 2,197,690.87 

Meter station at Copper Cliff 2,290 . 63 



Note. — The assets of Ontario Power Service Corporation 
Limited acquired by the Commission — on behalf of the 
Province — consisted of: 

(1) The uncompleted Abitibi Canyon Development and 
Lines upon which $15,146,607.31 has been expended; 

(2) $2,697,392.69 unexpended cash in the hands of the 
Trustee and Receiver, and the purchase price of 
$14,000,000 was paid: 

(a) In twenty-year debentures of the Commission, 
guaranteed by the Province, maturing in 1952 and 
bearing interest at the rates 33^ per cent in first five 
years, 4 per cent in next five years, 5 per cent in last 
ten years — to the amount of $17,626,950, and 

(b) In cash $290,150 to the Receiver: 
From the par value of the above mentioned 

bonds $17,626,950.00 

may be deducted the amount of cash 
turned over to the Commission by 
the Receiver 2,697,392 .69 



and to the balance is added: 

(1) The cash paid to the Receiver, as 

above 

In settlement of certain claims 

Expenditures by the Commission to 
31st October, 1933 incidental to the 
purchase of the properties and to- 
wards completion of such properties 



$14,929,557.31 



(2) 
(3) 



290,150.00 
57,406.22 



1,452,668.92 



Total to 31st October, 1933 — as shown 

above $16,729,782.45 

and leaving in the hands of the Com- 
mission a balance in cash of 
$897,167.55 



Patricia District: 

Ear Falls generating plant. 

Manitoulin Island: 

Transformer station , 

Rural power district 



Bonnechere River Storage: 
Round Lake dam 



Service Buildings and Equipment: 

Service buildings and equipment, Toronto 

Terminal building, Hamilton 

Equipment of storehouse and garage, Hamilton 
Pole yard and equipment, Cobourg 



18,929,763.95 



$5,098.11 
27,527.68 



482,224.95 

32,625.79 
51,629.23 



$508,098.10 

750,000.00 

3,666.40 

21,629.08 



1,283,393.58 



Carried forward $282,261,810. 15 



1934 HYDRO-ELECTRIC POWER COMMISSION [43 

COMMISSION OF ONTARIO 

and Liabilities, October 31, 1933 

TAKINGS— Continued 

Liabilities 
Brought forward $9,196,275.00 $249,517,852.07 

Guaranteed 43^% debenture stock, due 1941, of the Toronto 
Power Company, Limited: 

Amount assumed at date of purchase of Com- 
pany by Commission, December 1, 1920. $13,558,917.81 
Less: Retired by the Commission 13,483,056.18 



$75,861.63 



Premium of 5 % payable under terms of Trust 
deed because of notice to retire before 
maturity 3,793.08 



79,654.71 



First mortgage 5 % gold bonds, due 1933, of the 
Electrical Development Company of Ontario, 
Limited: 

Amount assumed at date of purchase of Com- 
pany by Commission, December 1, 1920. . $4,335,000.00 
Less: Retired by the Commission 4,328,500.00 



6,500.00 
9,282,429.71 



Other debentures assumed: 

In respect of purchase of lines at Streetsville: 

Amount assumed at date of purchase. . . $6,000.00 

Less: Retired by the Commission 5,541 .46 



$458.54 
Interest accrued thereon 11 .46 



$470.00 



In respect of purchase of original Muskoka 
Power Development: 

Amount assumed at date of purchase. . . $50,595 .93 
Less: Retired by the Commission 34,101 . 75 

$16,494.18 
Interest accrued thereon 634 . 34 



17,128.52 



In respect of purchase of sundry rural lines: 

Amount assumed at dates of purchase. . $69,289.85 
Less: Retired by the Commission. ...... 35,571 .24 

$33,718.61 
Interest accrued thereon 872 .47 



34,591.08 



Outstanding share capital of the Electrical Development 

Company of Ontario, Limited $600.00 

Galetta Electric Power and Milling Company Limited 580.00 



52,189.60 

1,180.00 

659,503.42 
Carried forward ■ $259,513,154.80 



Accounts payable $602,435 .60 

Interest coupons due but not yet presented for payment. . . . 57,067 .82 



H4 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

HYDRO- ELECTRIC POWER 

Detailed Statement of Assets 

POWER UNDER 

A CCCTC 

Brought forward $282,261,810. 15 

Office Buildings: 

On University avenue, Toronto $525,007.00 

On proposed new building 138,450 . 36 

On corner Elm street and Centre avenue, Toronto 160,821 .95 

824,279.31 



Office Furniture and Equipment: 

At Toronto office $61,829.27 

At Electrical Inspection office 6,876 . 22 



68,705.49 
Automobiles and Trucks 3,737 . 67 

Inventories: 

Construction and maintenance tools and equipment $831,094.20 

Construction material and sundry supplies 894,564.34 

Maintenance material and supplies 631,837 .30 

Stationery and office supplies 24,990 . 91 



2,382,486.75 



Sinking Funds: 

Employed to make repayments to the Province 
of Ontario under the terms of the Power 
Commission Act $17,008,616.73 

Employed in retirement of bonds issued or 
assumed by the Commission and guar- 
anteed by the Province of Ontario 7,991,128.38 



Invested in securities of the Province of Ontario, which stand: 

(a) Deposited with the Provincial Treasurer— par value, 
$2,101,000.00 . $2,087,573 .08 

(b) In the hands of the Commission — par value, 

$300,000.00 295,200.00 

Interest accrued thereon 33,162.01 



2,415,935.09 



Insurance Funds: 

(a) Invested in securities of the Dominion of Canada — par 

value, $800,000.00. $802,430.84 

(b) Invested in securities of the Province of Ontario — par 

value, $28,000.00 28,727 . 24 

Interest accrued thereon 616.53 



$831,774.61 
(c) On deposit with Workmen's Compensation Board 48,543 .01 



880,317.62 



Staff Pension Funds: 

(a) Invested in securities of the Province of Ontario — par 

value, $3,270,000.00 $3,235,755.95 

(b) Invested in securities of the Dominion of Canada — par 

value, $95,000.00 93,427.00 

Interest accrued thereon 37,250 . 14 



3,366,433.09 



Carried forward $292,203,705. 17 



1 934 HYDRO-ELECTRIC POWER COMMISSION 143 

COMMISSION OF ONTARIO 

and Liabilities, October 31, 1933 

TA KINGS— Continued 

Liabilities 
Brought forward $259,513,154.80 

Bank of Montreal: 

Short term loan (guaranteed by Province of Ontario) 2,500,000 .00 

Other short term loan (secured by pledge of Dominion of 

Canada and Province of Ontario Bonds) 3,300,000.00 

Insurance Department: 

Outstanding claims and awards $816,542 . 62 

Surplus 121,561 .38 

938,104.00 

Reserve for Staff Pensions 3,384,757 .69 

Balances due to Municipalities following the annual adjustments 
in respect of power supplied to them up to October 31, 1933, 
in reduction of the amounts charged to them by monthly 
interim bills: 

Niagara system $810,579.69 

Georgian Bay system 74,760 . 04 

Eastern Ontario system 131,601 .92 

Nipissing rural power district 8,987 .75 



1,025,929.40 



Reserves for Sinking Fund: 

Niagara system $24,564,512 . 19 

Niagara rural lines 14,046 . 12 

Thunder Bay system 1,063,953 .45 

Georgian Bay system 936,659 . 56 

Georgian Bay rural lines 846 .41 

Eastern Ontario system 1,064,379.57 

Nipissing rural power district 682 . 76 

Bonnechere storage 3,536 .97 

Manitoulin rural power district 285 .45 

$27,648,902.48 

Service buildings and equipment 120,334 . 12 

Office buildings 156,249 . 61 



27,925,486.21 



Reserves for Renewals: 

Niagara system $18,686,189.89 

Niagara rural lines 6,204 . 62 

Thunder Bay system 1,325,319.49 

Georgian Bay system 1,454,220.59 

Georgian Bay rural lines 517.15 

Eastern Ontario system 3,142,627 .03 

Northern Ontario properties 413,679 . 10 

Nipissing rural power district 3,800 .33 

Manitoulin rural power district 996.29 

$25,033,554.49 

Service buildings and equipment 315,079 .89 

Office buildings 115,185 .37 

25,463,819.75 

Carried forward $324,051,251.85 



146 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

HYDROELECTRIC POWER 

Detailed Statements of Assets 

POWER UNDER 
Assets 

Brought forward $292,203,705.17 

Reserve Funds: 

(a) Invested in securities of the Dominion of Canada — par 

value, $2,501,850.00 $2,503,517.83 

(b) Invested in securities of the Canadian National Railway, 

guaranteed by the Dominion of Canada — par value, 

$50,000.00 52,592 .03 

(c) Invested in securities of the Province of Ontario — par 

value, $29,618,500.00 29,207,884.53 

(d) Invested in securities of the Commission guaranteed by 

the Province of Ontario— par value, $1,200,000.00. . . 1,185,212.40 

(e) Invested in securities of the Temiskaming and Northern 

Ontario Railway, guaranteed by the Province of 

Ontario— par value, $240,000.00 207,01 1.57 

(f) Invested in debentures of Ontario municipalities, which 

debentures were received from certain municipalities 
upon the sale thereto of their local distribution 

systems— par value, $1,439,244.34 1,324,159 .94 

Interest accrued thereon 425,111 .98 



Other bonds and shares taken over with the plant assets of power 

companies acquired — carried at a value of $24,915.00 $24,915 .00 

Interest accrued thereon 332 .51 



34,905,490.28 



25,247.51 



Cash: 

In banks $2,066,558.17 

In banks to pay debenture stock and bonds overdue but not 

presented 86,154.71 

In banks to pay bond interest due November 1, 1933, and 

interest coupons overdue but not presented 88,942 .82 

Sinking funds on deposit with trustees for bondholders 775 .57 

In hands of employees as'advances on account of expenses . . . 76,532 .71 



$2,318,963.98 



Less: Funds of Guelph Radial Railway shown elsewhere in 

this balance sheet 6,846 . 28 



2,312,117.70 



Accounts Receivable: 

Due by municipalities and sundry customers 
in respect of construction work, supply 
sales, etc $323,007.42 

Less: Reserve for doubtful accounts 22,797 . 14 



Due by municipalities and sundry customers 

in respect of power accounts $4,091,739.92 

Less: Reserve for doubtful accounts 665,798.60 



$300,210.28 



3,425,941.32 



Sinking fund and interest accounts owing in respect of rural 

lines 3,848.04 



3,729,999.64 
Carried forward $333,176,560.30 



1934 HYDRO-ELECTRIC POWER COMMISSION 147 

COMMISSION OF ONTARIO 

and Liabilities, October 31, 1933 

TA KINGS— Continued 

Liabilities 

Brought forward $324,051,251.85 

Reserves for Obsolescence and Contingencies: 

Niagara system $9, 106,600 . 64 

Niagara rural lines 3,047 .63 

Thunder Bay system 715,396.31 

Georgian Bay system . . . . : 429,836.32 

Georgian Bay rural lines 222.36 

Eastern Ontario system 1,131,109.22 

Northern Ontario properties 211,603.46 

Nipissing rural power district 1,317 .98 

Manitoulin rural power district 476 .90 

11,599,610.82 

Balance at credit of Interest Account 20,221 . 23 

Contingent Liabilities: 

In respect of contracts entered into for power undertakings 
in course of construction, $165,265.78. 



Carried forward $335,671,083.90 



H8 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

HYDRO-ELECTRIC POWER 

Detailed Statement of Assets 

POWER UNDER 

Assets 

Brought forward $333,176,560.30 

Balances due by Municipalities — following the annual adjust- 
ment — in respect of power supplied to them up to October 
31, 1933, in addition to the amounts charged to them by 
monthly interim bills: 

Niagara system $484,288 . 1 1 

Georgian Bay system 111,697.27 

Eastern Ontario system 88,975 .05 

Thunder Bay system 101,293.11 

Manitoulin rural power district 1,383 .84 

787,637.38 



Rural Loans: 

Loans made to persons under provisions of the Rural Power 
District Loans Act in respect of installations of electrical 
equipment $84,912 .64 

Instalments of principal received 20,767 . 22 



$64,145.42 
Interest instalments due 896.83 



Work in Progress: 

Expenditures to date incidental to Water 
Heater Campaign, including purchases of 
materials, also engineering, administration, 
printing, advertising, etc $387,693 .89 

Less: portion written off against revenue in 

year ending October 31, 1933 63,547 . 14 



Expenditure on account of various systems 
chargeable upon completion to: 

Capital construction $22,011 .36 

Operating and maintenance expenses 22,553 .65 



$324,146.75 



44,565.01 



65,042.25 



368,711.76 
Insurance Unexpired 37,242 .26 



Discount on Debentures issued by the Commission, less amounts 
written off: 

On debenture issue of $3,200,000 maturing 1941 $67,650 .81 

On debenture issue of $4,000,000 maturing 1939 41,018.40 

108,669.21 

Total Power Undertakings $334,543,863. 16 



1934 HYDRO-ELECTRIC POWER COMMISSION 149 

COMMISSION OF ONTARIO 
and Liabilities, October 31, 1933 

TA KINGS— Continued 

Liabilities 
Brought forward $335,671,083.90 



Total Power Undertakings $335,671,083.90 



150 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

HYDROELECTRIC POWER 
Detailed Statement of Assets 

RADIAL RAILWAY 

Assets 
Brought forward $334,543,863. 16 

Guelph Radial Railway: 

Road and equipment $444,205 . 06 

Materials and supplies 5,499 . 14 

Reserve funds: 

(a) Invested in securities of the Province 

of Ontario— par value, $25,000.00 $22,534.90 

(b) Invested in securities of the Dominion 

of Canada— par value, $25,000.00 24,779.92 

Interest accrued thereon 1,057.66 

48,372.48 

Cash: 

In the general bank account of the Com- 
mission at Toronto $6,846 . 28 

In bank at Guelph 1,496.99 

In hands of employees as advances on 

account of expenses 900 .00 

9,243.27 

Accounts receivable: $1 , 782 . 1 2 

Less: Reserve for doubtful accounts 500.00 

1,282.12 

Insurance and expenses prepaid 1 ,014 . 90 

Due by the City of Guelph: 

Operating deficit for the year ending 

October 31, 1933 — as per Operating 

Account $41,332 .32 

Less: Paid on account, by the City 38,000.00 

3,332.32 

512,949.29 

Sandwich, Windsor & Amherstburg Railway Company: 

Undertakings of the Sandwich, Windsor and Amherstburg 
Railway Company to pay the Hydro Radial Debentures 
issued by the Commission, and guaranteed by the 
Province of Ontario, in purchase of, and for the extension 
and betterment of, the Sandwich, Windsor and Amherst- 
burg Railway — as per agreement covering the transfer 
at July 31st, 1931, of the Railway, by the Commission, 
to the Company $5,816,205 .00 

Interest accrued on such debentures 61,839 . 63 

Note. — The Hydro Radial Debentures above mentioned 
(and which are also listed opposite as liabilities of the 
Commission) are — under Statute of 1930 and under 
Trust Deed, dated July 31, 1931, in favour of the 
Guaranty Trust Company, as Trustee — secured by: 

(a) A charge upon the properties of the Railway. 

(b) Debentures of the eleven municipalities which 

own the Railway Company, to the aggregate 

amount of $5,816,205.00. 5,878,044 . 63 

Carried forward $340,934,857.08 



1934 HYDRO-ELECTRIC POWER COMMISSION \5\ 

COMMISSION OF ONTARIO 
and Liabilities, October 31, 1933 

UNDER TA KINGS— Continued 

LlABILITES 

Brought forward $335,671,083.90 

In respect of the Guelph Radial Railway: 

City of Guelph — purchase price of the Railway 
payable thereto, in half yearly instalments 

according to purchase agreement $150,000 .00 

Less: Twenty- five instalments thereon. . . 81,856.05 

$68,143.95 



Debentures issued by the Commission and 
guaranteed by the Province of Ontario: 

Five per cent Debentures due 1970, issued 
for the purpose of making extensions 
and betterments 300,000.00 

Accounts payable and accrued charges $794.42 

Provision for unredeemed tickets 1,300.00 

2,094.42 

Premium on sale of debentures — less portion written off. . . . 21,229. 14 

Reserve— created by payment of instalments on the purchase 
price out of the revenue of the road and assessments 
against the City of Guelph ' 81,856.05 

Reserve for sinking fund 8,152 . 75 

Reserve for renewal of road and equipment 31,472 .98 



In respect of the Sandwich, Windsor & Amherstburg Railway 
Company: 

Debentures issued under provisions of the Hydro-Electric 
Railway Act, by the Commission and guaranteed by 
the Province of Ontario in purchase of the Railway and 
for the purpose of making extensions and betterments 
thereto. 

Four and one-half per cent debentures, due April 1, 1960 $2,100,000.00 

Six per cent debentures, due July 1, 1961 900,000 .00 

Five per cent debentures, due September 1, 1943 966,205 .00 

Five per cent debentures, due July 1, 1945 750,000.00 

Five per cent debentures, due September 1, 1945 100,000.00 

Five per cent debentures, due July 15, 1946 1,000,000.00 

$5,816,205.00 
Interest accrued thereon 61,839.63 



512,949.29 



5,878,044.63 



Carried forward $342,062,077.82 



152 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

HYDRO-ELECTRIC POWER 
Detailed Statement of Assets 

RADIAL RAILWAY 

Assets 

Brought forward $340,934,857.08 

Toronto and York Radial Railway: 

City of Toronto — debentures held as collateral security for 
the repayment of the Hydro Radial debentures issued in 
purchase of the Toronto and York Radial Railway — as 
per agreement covering the transfer (in January, 1927) 
of the railway to the City of Toronto $2,375,000.00 

City of Toronto — interest accrued on $2,375,000 debentures 
issued by the Commission in purchase of the Toronto 

and York Radial Railway 59,375 .00 

2,434,375.00 



Port'Credit to St. Catharines Radial Railway: 

Purchase of right-of-way and carrying charges (taxes, less 

rental revenue) down to October 31, 1933 $73,421 .81 

Construction materials purchased, less amount realized on 

sale thereof 117,510.09 

Surveying, engineering, administrative expenses and interest 399,969.62 

590,901.52 



Toronto to Port Credit Radial Railway: 

Purchase of right-of-way and carrying charges (taxes, less 
rental revenue) down to October 31, 1933 — less amounts 
realized on properties sold $486,044 . 65 

Surveying, engineering, administrative expenses and interest 550,274.57 

1.036,319.22 



Total $344,996,452.82 



1934 HYDRO-ELECTRIC POWER COMMISSION 153 

COMMISSION OF ONTARIO 
and Liabilities, October 31, 1933 

UNDERTAKINGS— Continued 

Liabilities 

Brought forward $342,062,077.82 

In respect of Toronto and York Radial Railway: 

Debentures issued by the Commission and guaranteed by 
the Province of Ontario: 

Six per cent debentures, due 1940, issued in purchase 
of the Metropolitan, Scarboro and Mimico 
Radial Railway divisions $2,375,000.00 

Interest accrued thereon 59,375 .00 

2,434,375.00 



In respect of the Port Credit to St. Catharines Radial Railway: 

Bank of Montreal — advances (secured by hypothecation of $1,200,000 Hydro 
Radial debentures, being part of an issue of $11,360,363 guaranteed by 
the Province of Ontario) 500,000 . 00 



Totai $344,996,452.82 



154 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

NIAGARA 

Operating Account for the 

Costs of operation as provided under the terms of the 
Power Commission Act 

Power purchased $6,738,406 . 63 

Costs of operation and maintenance, including the proportion of 
administrative expenses chargeable to the operation of 
this system: 

Generation and transmission equipment $4,187,507.27 

Rural power districts 557,105 .44 

Water heater costs written off in year to extent of revenue 

available from water heater loads 55,561 .07 

4,800,173.78 

Interest (including exchange thereon) on capital investment in: 

Generation and transmission equipment $10,151,547.62 

Rural power districts 294,442 .54 

10,445,990.16 

Provision for renewals of: 

Generation and transmission equipment $1,376,778.87 

Rural power districts 251,397.57 

1,628,176.44 

Provision for obsolescence and contingencies in respect of: 

Rural power districts $125,698 . 79 

125,698.79 

Provision for sinking funds for repayment of the cash advances by 
the province of Ontario to the Commission and for the 
retirement of the bonds issued by and assumed by the 
Commission: 

By charges included in the cost of power delivered to munici- 
palities and rural power districts $1,385,325 .62 

By charges against contracts with private companies which 

purchased pow r er and local distribution systems 431,003 .02 

By charges included in the cost of distribution of power within 

rural power districts 66,871 .35 

1,883,199.99 

Total costs of operation $25,621,645.79 

Deduct: 

Cost to the Commission (including provisions for sinking fund 
$431,003.02 and renewals $312,153.93) of power delivered 
to private companies and customers under flat rate 
contracts, in excess of the revenue received from them — 
which excess has been charged against the Contingency 
Reserve of the system $2,221,034.43 

Amount appropriated from the Contingency Reserve of the 
system and applied proportionately to each municipality 

in. reduction of the costs of operation 2,015,572 .30 

4,236,606.73 

$21,385,039.06 



1934 HYDRO-ELECTRIC POWER COMMISSION 155 

SYSTEM 

Year Ending October 31, 1933 

Revenue for Period 

Amounts received from (or billed against) each municipality by 

the Commission $15,136,167.92 

Power sold to private companies and customers, also miscellaneous 

revenue 3,817,900 .47 

Amounts received from (or billed against) customers in rural power 

districts . 2,063,370 . 73 

Power supplied at cost to Sandwich, Windsor & Amherstburg 
Railway Company and certain fixed < harges billed against 
Windsor, Essex & Lake Shore Electric Railway Association.. 79,282.94 

$21,096,722.06 

Add: 

Amounts due by certain municipalities, being the difference 
between the sums received (or billed) at interim rates 
and the amounts charged — following annual adjustment — 
in respect of power supplied in the year $320,603 .06 

Amounts due by municipalities comprising certain rural power 
districts, being the difference between the sums received 
from (or billed against) customers therein and the amounts 
charged to such districts — following annual adjustment — 

in respect of power supplied in the year 92,501 .40 

413,104.46 



$21,509,826.52 



Deduct: 

Amounts received from (or billed against) certain municipali- 
ties at interim rates in excess of the amounts charged — 
following annual adjustment — in respect of power supplied 
in the year $74,541 .31 

Amounts received from (or billed against) customers in certain 
rural power districts in excess of the amounts charged to 
such districts — following annual adjustment — in respect 

of power supplied in the year 50,246 . 15 

124,787.46 

Revenue $21,385,039.06 



$21,385,039.06 



Note — Operating account of Hamilton Street Railway Company is shown on page 274. 



156 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the amount chargeable (upon annual adjustment) to each 

by the Commission; the amount appropriated from the contingency 

cost; the amount received by the Commission from each 

charged to each Municipality in respect of power 



Municipality 



Interim rates 

per 
horsepower 
collected by 
Commission 
during year 



To 

Jan. 1 

1933 



To 

Oct. 31 

1933 



Share of 
capital cost 
of system on 

which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



Acton 

Water heater load. 
Agincourt 

Water heater load. 

Ailsa Craig 

Alvinston 

Amherstburg 

Water heater load. 

Ancaster twp 

W 7 ater heater load 

Arkona 

Aylmer 

Water heater load 

Ayr 

Baden 



Beachville 

Water heater load 
Belle River 

Water heater load 
Blenheim 

Water heater load 

Blyth 

Bolton 

Water heater load 

Bothwell 

Water heater load 
Brampton 

Water heater load 
Brantford 

Water heater load 
Brantford twp 

Water heater load 
Bridgeport 

Water heater load 



Brigden. 

Brussels 

Bur ford. . . . 
Burgessville 
Caledonia. . 



$ c. 
33.00 



40.00 



48.00 
90.00 
40.00 



30.00 



75.00 
35.00 



35.00 
32.00 

33.00 



38.00 



39.00 



58.00 
46.00 



45.00 



29.00 



$ c. 
33.00 



40.00 



48.00 
90.00 
38.00 



30.00 



75.00 
35.00 



34.00 
32.00 

33.00 



38.00 



39.00 



58.00 
44.00 



45.00 



$ c. 
243,602.11 



4,9,545.82 



36,770.85 

61,292.09 

193,881.50 



68,899.46 



33,234.98 
138,589.66 



47,654.46 
75,357.51 

128.358.54 



36,481.80 



113,363.81 



40,808.82 
44,228.76 



36,460.59 



27.00 
29.00 
36.00 



68.00 
54.00 
35.00 
44.00 
29.00 



30.00 



27.00 
30.00 
36.00 



65.00 
54.00 
35.00 
50.00 
29.00 



534,738.02 
2,800,848.27 



144,015.51 
'32,429 '42 



37,902.77 
49,993.30 
41,994.31 
16,577.41 
73,657.68 



784.6 

2.5 

136.3 

0.1 

89.2 

74.9 

587.0 

9.6 

246.2 

1.5 

52.7 

440.6 

0.3 

162.7 

253.7 

440.5 

0.8 
109.1 

0.3 
336.1 

1.8 

87.6 

119.4 

0.8 

96.9 
0.4 

2,003.6 

4.8 

11,548.4 

19.6 

551.1 

1.2 

102.1 

0.3 

69.6 
114.1 
140.6 

40.1 
259.2 



$ c. 
6,798.72 



1,181.07 



772.94 

649.02 

5,086.48 



2,133.37 



456.66 
3,817.89 



1,409.83 
2,198.36 

3,817.02 



945 


37 


2,912 


37 


759 
1,034 


07 

63 


839 


66 


17,361 


60 


100,069 


22 


4,775 


39 


884 


72 



603 . 10 
988.70 

1,218.33 
347.48 

2,246.02 



$ c. 

6,021.07 

*84 . 89 

1,288.89 

*3.94 

1,636.43 

1,937.56 

5,161.93 

*349.60 

1,997.99 

*48.43 
1,483.80 
4,156.84 

*10.79 
1,592.46 
2,146.68 

3,529.00 

*26.29 
1,367.92 

*12.14 
3,763.76 

*70.62 
1,544.97 
1,291.32 

*32.89 

1,659.09 

*19.01 

16,929.76 

*151 .59 

66,539.77 

*555.01 

4,999.47 

*38.32 

1,048.85 

•11.16 

1,348.57 
1,892.64 
1,289.39 
871.19 
2,085.73 



$ c 
12,201.19 



2,460.08 



1,769.18 
2,888.73 
9,666.41 



3,497.22 



1,596.20 
6,913.83 



2,392.25 
3,734.06 

6,433.39 



1,816 


94 


5,603 


33 


1,984 
2,154 


35 
97 


1,752 


05 


27,085 


25 


142,183 


.68 


7,376.35 


1,635 


.51 



1,812.55 
2,434.21 
2,101.43 
806.01 
3,700.36 



'Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



157 



SYSTEM 



N.—COST OF POWER 



Municipality as the Cost — under Power Commission Act — of Power supplied to it 
reserve of the system and proportionately applied in reduction of such 
Municipality; and the amount remaining to be credited or 
supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Sinking 
fund 



Total 
cost of 

power 
for year 



Amount 
appropriat- 
ed from 
contingency 
reserve 
and pro- 
portionate- 
ly applied 
in reduc- 
tion of such 
cost 



Amounts 

charged 

to each 

municipality 

in respect 

of power 

supplied 

to it in 

the year 



Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 



Amounts remaining 

to be credited 

or charged to each 

municipality 



Credited 



Charged 



$ c. 
2,085.88 


$ c. 
2,280.31 


442.11 


472.07 


371.91 

765.04 
1,685.51 


354.57 

618.41 

1,830.67 


545.01 


636.47 


388.91 
1,193.74 


330.25 
1,299.83 


389.78 
621.74 

1,043.31 


443 . 10 
701.97 

1,192.71 


319.92 


344.92 


1,011.75 


1,072.13 


433.55 
422.60 


397.33 
422.97 


346.85 


347.82 


4,006.01 


4,907.08 


21,022 23 


25,681.31 


1,059.27 


1,317.71 


281 74 


304.64 


425.13 
517.29 
349.21 
168.39 
587.67 


374.03 
484.25 
391.61 
160.12 
679.83 



$ 


c. 


29,387 


.17 


84.89 


5,844 


22 


3 


94 


4,905 


.03 


6,858 


76 


23,431 


.00 


349 


60 


8,810 


06 


48 


43 


4,255 


82 


17,382 


13 


10 


79 


6,227 


42 


9,402 


81 


16,015 


43 


26 


29 


4,795 


07 


12 


14 


14,363 


34 


70 


62 


5,119 


27 


5,326 


49 


32 


89 


4,945 


47 


19 


01 


70,289 


70 


151 


59 


355,496 


21 


555 


01 


19,528 


19 


38 


32 


4,155 


46 


11 


16 


4,563 


38 


6,317 


09 


5,349 


97 


2,353 


19 


9,299 


61 



$ c 
\ 2,746.10 



477 


05 


312 

262 

2,054 


20 

15 
50 


861 


70 


184 
1,542 


45 
10 



569.45 
887.95 

1,541.75 



381 


85 


1,176 


35 


306 

417 


00 

90 


339 


15 


7,012 


60 


40,419 


40 


1,928 


85 


357 


35 



243 . 60 
399.35 
492 . 10 
140.35 
907.20 



$ 


c. 


26,641 


.07 


84 


.89 


5,367 


.17 


3 


.94 


4,592 


.83 


6,596 


.61 


21,376 


.50 


349 


.60 


7,948 


.36 


48 


43 


4,071 


37 


15,840 


03 


10 


79 


5,657 


97 


8,514 


86 


14,473 


68 


26 


29 


4,413 


22 


12 


14 


13,186 


99 


70 


62 


4,812 


67 


4,908 


59 


32 


89 


4,606 


32 


19 


01 


63,277 


10 


151 


59 


315,076 


81 


555 


01 


17,599.34 


38 


32 


3,798 


11 


11 


16 


4,319 


78 


5,917 


74 


4,857 


87 


2,212 


84 


8,392 


41 



$ c. 
\ 26,712.95 

5,603.20 

4,382.79 

6,926.75 

23,480.33 



7,639.28 

4,057.01 
\ 15,844.65 

/ 

5,702.71 
8,346.00 

14,952.55 

4,262.57 

13,517.39 

5,205.58 
5,471.14 

4,487.44 

61,536.07 

311,164.45 

16,904.56 

3,782.23 



4,674.96 
6,313.81 
5,047.46 
2,004.39 

7,732.85 



$ c 



232.09 



330.14 
1,754.23 



44.74 



452.58 



259.78 

392.91 
529.66 



355.18 
396.07 
189.59 



$ c. 
13.01 



210.04 



357.51 

14.36 
6.17 



168.86 



162.79 



137.89 
1,892.62 
4,467.37 

733.10 
27.04 



208.45 
659.56 



158 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the amount chargeable (upon annual adjustment) to each 

by the Commission; the amount appropriated from the contingency 

cost; the amount received by the Commission from each 

charged to each Municipality in respect of power 



Municipality 



Interim rates 

per 
horsepower 
collected by 
Commission 
during year 



To 

Jan. 1 

1933 



To 

Oct. 31 

1933 



Share of 
capital cost 
of system on 

which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange^ 



Campbellville 

Cayuga 

Chatham 

Water heater load 
Chippawa 

Water heater load 
Clifford 



Clinton. . . 
Comber. . . 
Cottam. . . 
Courtright 
Dashwood . 



Delaware 

Water heater load 
Dorchester 

Water heater load 
Drayton 

Water heater load 
Dresden 

Water heater load. 
Drumbo 

Water heater load 



Dublin 

Dundas 

Water heater load 

Dunnville 

Dutton 

Water heater load 
East Windsor 

Water heater load 

Elmira 

Water heater load. 
Elora 

Water heater load. 
Embro 

Water heater load. 
Erieau 

Water heater load. 
Erie Beach 



$ c 
62.00 
50.00 
30.00 



25.00 



59.00 

38.00 
50.00 
44.00 
72.00 
50.00 

38.00 



38.00 



58.00 
45.00 
45.00 



58.00 
25.00 



35.00 
38.00 



31.00 



34.00 
35.00 



50.00 
56.00 
70'00 



$ c 
60.00 
48.00 
30.00 



25.00 



59.00 

38.00 
50.00 
44.00 
72.00 
50.00 

38.00 



38.00 



58.00 
45.00 
45.00 



58.00 
25.00 



34.00 
38.00 



31.00 



34.00 



35.00 
48.00 



56.00 
70.00 



$ c. 

8,554.80 

42,983.36 

1,069,849.84 



43,910.02 

"29,254 ! 87 

147,343.39 
51,719.24 
23,215.62 
23,042.55 
21,950.30 

10,460.48 



27,127.73 
44, 952 .50 



99,732.05 
21,82^76 



18,213.53 
323,823.83 



225,632.91 
63,104.22 



680,732.50 



187.060.34 



92,017.99 
34,248.56 



31,739.99 
6,994.65 



25.1 

99.2 

3,811.3 

23.9 

196.5 

1.9 

56.7 

436.6 

124.7 

59.9 

39.4 

50.2 

36.1 

1.0 
77.4 

0.4 
89.9 

0.1 
269.4 

0.5 
64.0 

0.2 

36.9 

1,285.4 

3.5 

766.8 

210.1 

0.1 

2,256.0 

19.8 

580.5 

4.1 

275.4 

0.4 

93.4 

0.5 

69.6 

0.1 

13.7 



$ c 

217.50 

859.59 

33,025.69 



1,702.71 



491.32 

3,783.23 

1,080.55 

519.05 

341.41 

434.99 

312.81 



670 


60 


779 


00 


2,334 


41 


554 


57 


319 
11,138 


75 

25 


6,644 
1,820 


48 
56 


19,548 


72 


5,030 


15 


2,386 


40 


809 


33 


603 


10 



118.71 



$ 


c. 


862 


.52 


1,892 


38 


26,834 


66 


*741 


55 


1,140 


30 


*49 


.16 


1,485 


51 


4.791 


07 


1,941 


06 


725 


64 


1,361 


01 


904 


58 


505 


55 


*38 


75 


1,113 


01 


*16 


78 


2,165 


04 


*6 


37 


3,899 


89 


*22 


43 


868 


67 


*8 


39 


806 


84 


6,590 


72 


*94 


27 


4,094 


26 


2.474 


00 


*3 


73 


15,469 


59 


*640.83 


5,225 


82 


*147 


12 


2,784 


70 


*15 


14 


1,472 


46 


*22 


84 


1,173 


14 


*5 


36 


348 


13 



S c. 

427.57 

2,087.01 

53,621.29 

"2,256.95 

1,414 '96 

7,275.15 
2,502.60 
1,151.78 
1,105.9? 
1,058.20 

525.77 



1,266 


8& 


2,167 


42 


4,898 


30 


1,080 


78- 


874.67 
16,336.13 


11,367 
3,160 


20 
21 


34,025 


34 


9,203 


85 


4,515 


58 


1,666.30 


1,554.0S 



339.44 



*Heater costs written off in vear to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



159 



SYSTEM 



N.— COST OF POWER 



Municipality as the Cost — under Power Commission Act — of Power supplied to it 
reserve of the system and proportionately applied in reduction of such 
Municipality; and the amount remaining to be credited or 
supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Rene\ 



Sinking 
fund 



Total 
cost of 

power 
for year 



Amount 
appropriat- 
ed from 
contingency 
reserve 
and pro- 
portionate- 
ly applied 
in reduc- 
tion of such 
cost 



Amounts 
charged 
to each 
municipality 
in respect 
of power 
supplied 
to it in 
the vear 



Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 



Amounts remaining 

to be credited 

or charged to each 

municipality 



Credited Charged 



$ c. 

78.02 

441.34 

8,228.93 



280.21 



323.22 

1,320.10 
519.74 

223.42 
264.45 
228.54 

84.09 



226.59 
491 '02 



944.35 



199.47 



197.98 
2,309.51 



1,901.74 
525.65 



5,511.24 



1,642.09 



830.70 
322^04 



333.49 
76^85 



$ c. 

81.01 

412.12 

9,880.44 



391 55 



287.09 

1,390.10 
499.13 
222.91 

228.43 
213.04 

96.87 



240.19 



440.11 



953.00 



206.70 



178.14 
2,946.76 



2,099.53 
589.24 



6,357.13 



1,760.27 



869.57 
323~68 



309.05 
' 68 ". 70 



% c. 

1,666.62 

5,692.44 

131,591.01 

741.55 

5,771.72 

49.16 

4,002.04 

18,559.65 
6,543.08 
2,842.80 
3,301.29 
2,839.35 



38.75 
3,517.36 

16.7 

6,042 59 

6.37 

13,029.95 

22.43 

2,910.19 

8.39 

2,377.38 

39,321.37 

94.27 

26,107.21 

8,569.66 

3.73 

80,912.02 

640 . 83 

22,862.18 

147.12 

11,386.95 

15.14 

4,593.81 

22.84 

3,972.86 

5.36 

951.83 



$ c 

87.85 

347.20 

\ 13,339.55 



687.75 



198.45 

1,528.10 
436.45 
209.65 
137.90 
175.70 



1,525.09 \ 126.35 



270.90 



\ 314.65 



942.90 



224.00 



129.15 
) 4,498.90 



2,683 80 

\ 735.35 

/■ 

1 
/■ 



7,896.00 



\ 2,031.75 

/ 

) 963 90 
/ 



326.90 

243 '. 60 

47^95 



$ c 

1,578.77 

5,345.24 

118,251.46 

741.55 

5,083.97 

49.16 

3,803.59 

17,031.55 
6,106.63 
2,633.15 
3,163.39 
2,663.65 

1,398.74 

38.75 

3,246.46 

16.78 

5,727.94 

6 

12,087.05 

22.43 

2,686.19 

8.39 

2,248.23 

34,822.47 

94.27 

23,423.41 

7,834.31 

3.73 

73,016.02 

640 . 83 

20,830.43 

147.12 

10,423.05 

15.14 

4,266.91 

22.84 

3,729.26 

5.36 

903.88 



$ c. 

1,543.65 

4,912.83 

118,469.37 

5,091.30 

3,431.58 

16,535.62 
6,385.33 
2,703.79 
2,910.07 
2,574.46 

1,441.99 

3,028.94 

5,355.23 

12,447.91 

2,953.38 



2,138.24 
1 33,396.53 

26,898.91 
1 8,178.43 

72,574.41 



/ 

) 20,436.94 



9,921.38 



4,640.33 



3,998.31 



981.29 



278.70 
70.64 



4.50 



338 A3 
258.80 



3,475.50 
340.39 



350.58 

263.69 

77.41 



$ c. 

35 . 1 2 

432.41 

523.64 

41.83 

372.01 

495.93 



253.32 
89.19 



234.30 
379.08 



109.99 
1,520.21 



1,082.44 

540.61 
516.81 



160 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the amount chargeable (upon annual adjustment) to each 

by the Commission; the amount appropriated from the contingency 

cost; the amount received by the Commission from each 

charged to each Municipality in respect of power 



Municipality 



Interim rates 

per 
horsepower 
collected by 
Commission 
during year 



To 

Jan. 1 
1933 



To 

Oct. 31 

1933 



Share of 
capital cost 
of system on 

which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



Essex 

Water heater load. 
Etobicoke twp 

Water heater load. 
Exeter 

Water heater load. 
Fergus 

Water heater load. 
Fonthill 

Water heater load. 

Forest 

Water heater load. 
Gait 

Water heater load. 
Georgetown 

Water heater load. 
Glencoe 

Water heater load. 
Goderich 

Water heater load. 



$ c. 
35.00 



29.00 
38.00 
35' 00 
34.00 



48.00 
27.66 
35.00 
58.00 
42.00 



Granton 

Water heater load 
Guelph 

Water heater load 

Hagersville 

Hamilton 

Water heater load 
Harriston 



50.00 
27.00 



31.00 
23.50 



Harrow 

Water heater load 

Hensall 

Hespeler 

Water heater load 
Highgate 

Water heater load 
Humberstone 



44.00 
40.00 



50.00 
29.00 



Ingersoll 

Water heater load 

Jarvis 

Kingsville 

Water heater load 
Kitchener 

Water heater load 
Lambeth 

Water heater load 



46.00 
28.00 
28.00 



38.00 
38.00 



27.00 
42.00 



$ c. 
35.00 



28.00 
38.00 
35 '00 
36.00 



48.00 
27.00 
35.00 
58.00 
42 '00 



50.00 
28.00 



31.00 
24.50 



44.00 
38.00 



50.00 
29.00 



48.00 
28.00 
28.00 



38.00 
38.00 



27.00 
42.00 



$ c. 
105,032.26 



790,357.84 
133, 7 14 .3 7 
'211,972! 65 

'29,584.77 



124,794.14 
1,425,076 '.37 
' 326, 244. i 7 
' "78,757.34 
'361,661.44 



23,491.47 
1,844,3 16 .85 



177,314.24 
18,808,727.40 



103,670.12 
111,039.96 



60,955.56 
445,148.80 



24,587.78 
"84,994 '57 
542,693.39 



58,523.85 
141.829.66 



3,644,588.90 
"33,398.95 



316.9 

0.8 

3,039.1 

35.7 

389.2 

1.9 
636.1 

2.8 
112.2 

1.5 



309.4 

0.9 
5,510.5 

9.0 
970.2 

1.9 
159.9 

0.4 
950.4 

8.2 

56.2 

0.3 

7,122.3 

17.4 

550.8 

76,884.1 

186.2 

277.5 



319. 

2, 

133 

1,712 

1 

62 

0. 

322. 



1,968.7 

3.6 

148.6 

405.3 

4.3 

14,083.7 

59.9 

97.3 

1.3 



$ c. 
2,746.00 



26,334 


42 


3,372 


50 


5,511 


94 


972 


24 


2,681 


01 


47,749 


60 


8,406 


98 


1,385 


57 


8,235 


41 


486 


98 


61,716 


17 


4,772 
666,216 


79 
32 


2,404 
2,767 


59 

67 


1,156 
14,839 


80 
16 


545 


04 


2,792 
17,059 


79 
18 


1,287 
3,512 


65 
11 


122,038 


12 


843 


12 



$ c. 

2,655.15 

*28.85 

16,209.72 

*981.61 

4,272.46 

*75 .12 

6,012.23 

*104.66 

1,174.56 

*50.39 

4,205.40 

*41.80 

34,927.33 

*259.20 

8,535.53 

*67.50 

2,969.92 

*23.07 

11,719.07 

*355.65 

1,180.90 
*16.40 

45,760.52 

*503.89 

4,876.82 

326,554.82 

*4,811.89 

4,644.08 

3,213.73 

*97.53 

2,131.21 

11,003.35 

*49.54 

946.45 

*9 35 

2,006^08 

13,755.71 

♦110.56 

2,042.11 

3,992.57 

*167.05 

79,336.20 

*1,686.66 

1,254.98 

*53.90 



$ c 
5,229.58 



40,476.31 
6,612.97 



10,565.22 
"l',5 16. 93 



6,127.95 
71,957 .36 



16,166.86 

3,806.32 

17',648'.27 



1,136.40 
93,407 .02 



8,63d 07 
963,113.90 



5,073.95 
5,542.91 



2,964.91 
22,744.66 



1,192.07 
' '4,346 '. 29 
27,332.73 



2,859.44 
7,028.77 



184,765.34 
"l, 654. 89 



*Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



161 



SYSTEM N.— COST OF POWER 

Municipality as the Cost — under Power Commission Act — of Power supplied to it 
reserve of the system and proportionately applied in reduction of such 
Municipality; and the amount remaining to be credited or 
supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Sinking 
fund 



Total 
cost of 

power 
for year 



Amount 
appropriat- 
ed from 
contingency 
reserve 
and pro- 
portionate- 
ly applied 
in reduc- 
tion of such 
cost 



Amounts 

charged 

to each 

municipality 

in respect 

of power 

supplied 

to it in 

the year 



Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 



Amounts remaining 
to be credited 

or charged to each 
municipality 



Credited 



Charged 



$ c. 
915.22 



5,719.02 



1,224.86 



1,910.22 



227.20 



1,234.36 



10,343.20 



2,956.63 
' ' 85l"22 

3.487 '41 



238.54 



13.451.78 



1,544.50 
129.735.34 



989.34 
1.000.12 



646.48 
3,248.52 



239.94 

o46.i7 

4,200.09 



576.99 
1,283.00 



26,433.13 
305 '56 



$ c. 
992.01 



7,229.59 



1,267.80 



2,002.54 



271.09 



1,202.54 



13,009.86 
'3.084 '62 



769.72 
3,456 '90 



226.36 
16,850 '69 



1,652.23 
170,356.44 



989.05 
1,054.37 



593.77 
4,067.06 



236.14 
"778.82 
5,005.73 



558.29 
1,347.70 



33,295.37 
"316A9 



$ c 

12,537.96 

28.85 

95,969.06 

981.61 

16,750.59 

75.12 

26,002.15 

104.66 

4,162.02 

50.39 

15,451.26 

41.80 

177,987.35 

. 259.20 

39,150.62 

67.50 

9,782.75 

23.07 

44,547.06 

355.65 

3,269.18 

16.40 

231,186.18 

503.89 

21,481.41 

2,255,976.82 

4,811.89 

14,101.01 

13,578.80 

97.53 

7,493.17 

55,902.75 

49.54 

3,159.64 

9.35 

10,570.15 

67,353.44 

110.56 

7,324.48 

17,164.15 

167.05 

445,868.16 

1,686.66 

4,375.04 

53.90 



$ c 
1,109.15 



10,636.85 
' 1,362 '. 20 



2,226.35 
"392.70 



1,082.90 



19,286.75 
"3,395 '.70 



559.65 
3.326.40 



196.70 
24, 928 '.05 



1,927.80 
269,094.35 



971.25 

,117.90 



467.25 
5,993.75 



220.15 
1,128.05 
6,890.45 



520.10 
1,418.55 



49,292.95 
"340.55 



$ c. 

11,428.81 

, 28.85 

85,332.21 

981.61 

15,388.39 

75.12 

23,775.80 

104.66 

3,769.32 

50.39 

14,368.36 

41.80 

158,700.60 

259.20 

35,754.92 

67.50 

9,223.10 

23.07 

41,220.66 

355.65 

3,072.48 

16.40 

206,258.13 

503.89 

19,553.61 

,986,882.47 

4,811.89 

13,129.76 

12,460.90 

97.53 

7,025.92 

49,909.00 

49.54 

2,939.49 

9.35 

9,442.10 

60,462.99 

110.56 

6,804.38 

15,745.60 

167.05 

396,575.21 

1,686.66 

4,034.49 

53.90 



$ c. 
1 11,422.60 

) 89,095.06 

\ 15,264.86 

\ 22,994.23 

) 4,141.26 

\ 15,280.61 

159,384.50 

35,014.74 

9,536.79 

40,149.12 

2,878.32 

^04,139.60 

17,563.88 
1,911,204.44 

12,522.39 

12,660.95 

6,853.88 
52,808.71 

3,083.63 

r 

9,279.98 

56,860.73 

5,808.52 
15,982.99 

392,768.37 

4,241.33 

f 



$ c. 



2,781.24 



321.55 

870.45 
424.70 



290.62 



102.52 



2,850.17 
134.79 



70.34 



152.94 



$ c. 
35.06 



198.65 
886.23 



807.68 



1,427.19 

210.56 

2,622.42 

1,989.73 
80,489.92 

607.37 



172.04 



162.12 

3,712.82 

995.86 



5,493.50 



62 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the amount chargeable (upon annual adjustment) to each 

by the Commission; the amount appropriated from the contingency 

cost; the amount received by the Commission from each 

charged to each Municipality in respect of power 



Municipality 



Interim rates 

per 
horsepower 
collected by 
Commission 
during year 



To 

Jan. 1 

1933 



To 

Oct. 31 

1933 



Share of 
capital cost 
of system on 

which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



La Salle 

Water heater load 
Leamington 

Water heater load 
Listowel 

Water heater load 
London 

Water heater load 
London Railway 

Commission 



London twp 

W T ater heater load 
Long Branch 

Water heater load 

Lucan 

Lynden 

Markham 

Water heater load 



Merlin 

Water heater load 
Merritton 

Water heater load 
Milton 

Water heater load 
Milverton 

Water heater load 
Mimico 

Water heater load 



Mitchell 

Water heater load 

Moorefield 

Mount Brydges 

Water heater load 

Newbury 

New Hamburg 

Water heater load 

New Toronto 

Water heater load 

Niagara Falls 

Niagara-on-the-Lake 

Water heater load 
Norwich 

Water heater load 
Oil Springs 



ft c. 
36.00 



37.00 

37!66 

26'00 



34.00 



29.00 



37.00 
40.00 
43.00 



45.00 



23.00 
34^00 



35.00 
26.00 



33.00 



61.00 
42.00 



52.00 
35.00 



30.00 



19.00 
27.00 



34.00 
45.00 



$ c. 
35.00 



$ c 
63,407.59 



37.00 
37.00 
26^00 



343,897.76 
261,715^70 

7,053', 406. 79 



34.00 



312,323.66 
94,623.02 



30.00 



183,962.18 



37.00 
40.00 
43.00 



39,444.97 
27,090.24 
71,114.45 



45.00 



33,765.03 



23.00 
34' 00 



578,017.16 
165,314.16 



35.00 
26~00 



90,993.40 
486,775 '29 



33.00 



123,079.96 



61.00 
42.00 



21,464.55 
26,632.82 



54.00 
35.00 



18,725.58 
139,549.43 



30.00 



1,260,255.14 



19.00 
27.00 



1,645,138.21 
107,216.16 



34.00 
45^00 



96,599.07 
63,928.56 



197.3 
0.8 

973.8 
6.1 

820.9 

2.1 

28,067.1 

265.8 

990.0 

323.6 
5.2 

679.0 
3.0 

127.4 
82.6 

221.2 
0.7 

85.6 

0.1 

2,715.2 

3.4 

542.1 

4.9 

283.4 

0.8 

1,981.4 

24.6 

414.9 

3.6 

41.4 

84.1 

0.7 

42.0 

444.7 

1.3 

4,618.0 

6.8 

8,347.8 

480.8 

1.7 

308.8 

1.1 

166.3 



$ c. 
1,709.64 



8,438.18 

7,iii '27 

243' 207 .12 



8,578.55 
2,804.06 



5,883 


67 


1,103 

715 

1,916 


95 

75 
74 


741 


74 


23,527 


76 


4,697 


41 


2,455 


72 


17,169 


23 


3,595 


19 


358 

' 728 


74 
74 


363 

3,853 


94 

42 


40,015 


91 


72,335 
4,166 


38 
23 


2,675 


81 



1,441.02 



$ c. 

1,683.75 

*28.48 

8,865.52 

*234.37 

9,882.39 

*81.49 

140,290.95 

*7,180.59 

11,590.42 

2,895.13 

*176.95 

4,109.14 

*89.22 
1,627.71 

999 . 24 
3,254.53 

*29.08 

1,313.44 

*4.74 

11,735.69 

*81.24 

6,256.99 

*181.04 

2,899.96 

*29.47 

10,271.61 

*660.21 

3,837.35 
*123.64 

1,042.21 

1,261.12 
*29.16 
754.55 

3,814.43 
*45.45 

27,946.31 

*200.99 

29,559.54 

3,685.10 

*47.27 

2,899.68 

*39.24 

1,902.73 



$ 

3,183 


c . 

3H 


17,118.95 


13,026 


69 


359,353 


94 


15,368.06 
4,799.64 


9,491 


13 


1,931 
1,316 
3,556 


29 
26 
29 


1,645 


53 


30,552 


92 


8,033 


10 


4,435 


33 


24,960.35 


6,126 


32 


1,030 

1,328 


55 
59 


911 
6,924 


17 

37 


63,546 


56 


86,261 
5,562 


49 
60 


4,785 


58 


3,108 


52 



*Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



63 



SYSTEM 



A 7 .— COST OF POWER 



Municipality as the Cost — under Power Commission Act — of Power supplied to it 
reserve of the system and proportionately applied in reduction of such 
Municipality; and the amount remaining to be credited or 
supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Sinking 
fund 



Total 
cost of 

power 
for year 



Amount 
appropriat- 
ed from 
contingency 
reserve 
and pro- 
portionate- 
ly applied 
in reduc- 
tion of such 
cost 



Amounts 

charged 

to each 

municipality 

in respect 

of power 

supplied 

to it in 

the year 



Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 



Amounts remaining 

to be credited 

or charged to each 

municipality 



Credited Charged 



$ c. 
540.14 


$ c. 
596.79 


3,129.55 


3,270.99 


2,252.24 


2,452.36 


49,470.11 


64,147.08 


2,701.67 
767.50 


2,934.27 
877.96 


1,390.91 


1,694.69 


333.66 
241.56 
578.41 


367.77 

254.75 
658.74 


332.25 


325.40 


3,427.03 


5,139.63 


1,393.33 


1,544.91 


787.16 


853.38 


3,298.60 


4,411.60 


1,000.38 


1,142.64 


237 57 
229.86 


210.71 
249.51 


194.16 
1,201 68 


181.53 
1,308.98 


9,556.14 


11,593.48 


8,600.00 
682.26 


14,314.55 
955.69 


830.80 


905.91 


616.25 


613.22 



$ c 

7,713.70 

28.48 

40,823.19 

234.37 

34,726.95 

81.49 

856,469.20 

7,180.59 

41,172.97 

12,144.29 

176.95 

22,569.54 

• 89.22 

5,364.38 

3,527.56 

9,964.71 

29.08 

4,358.36 

4.74 

74,383.03 

81.24 

21,925.74 

181.04 

11,431.55 

29.47 

60,111.39 

660.21 

15,701.88 

123.64 

2,879.78 

3,797.82 

29.16 

2,405.35 

17,102.88 

45.45 

152,658.40 

200.99 

211,070.96 

15,051.88 

47.27 

12,097.78 

39.24 

7,681.74 



$ c. 
1 690.55 



3,408.30 



2,873.15 



98,234.85 



3,465.00 



1,132.60 



2,376.50 



445.90 
289.10 
774.20 



299.60 



9,503.20 



1,897.35 



991.90 
6,934.90 



1,452.15 



144.90 
294.35 



147.00 
1,556.45 



16,163.00 



29,217.30 
1,682.80 



1,080.80 
"582.05 



% 


c. 


7,023 


15 


28 


48 


37,414 


89 


234.37 


31,853 


80 


81 


49 


758,234.35 


7,180 


59 


37,707 


97 



11,011.69 

176.95 

20,193.04 

89.22 

4,918.48 

3,238.46 

9,190.51 

29.08 

4,058.76 

4.74 

64.879.83 

81.24 

20,028.39 

181.04 

10,439.65 

29.47 

53,176.49 

660.21 

14,249.73 

123.64 

2,734. 

3,503.47 

29.16 

2,258.35 

15,546.43 

45.45 

136,495.40 

200.99 

181,853.66 

13,369.08 

47.27 

11,016.98 

39.24 

7,099.69 



$ c. 
7,155.87 

37,255.70 

31,231.18 

757,905.02 

29,374.36 

11,466.99 

20,900.40 

4,832.79 
3,386.21 
9,763.12 




14,177.53 

2,562.95 
3,641.02 

2,308.89 
16,031.81 



142,537.58 

163,448.92 
13,349.55 

10,835.511 

7,678.521 



$ c 
104.24 



278.35 
618.14 



147.75 
543.53 



108.39 

50.54 
439.93 



5,841.19 



578.83 



393.56 

704 . 1 1 

7,509.92 

8,333.61 



85.69 



103.28 
719.66 
1,119.83 
251.62 
195.89 

195.84 
171.93 



18,404.74 
66.80 

220.71 



164 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the amount chargeable (upon annual adjustment) to each 

by the Commission; the amount appropriated from the contingency 

cost; the amount received by the Commission from each 

charged to each Municipality in respect of power 



Municipality 



Interim rates 

per 
horsepower 
collected by- 
Con! mission 
during year 



To 

Jan. 1 

1933 



To 

Oct. 31 

1933 



Share of 
capital cost 
of system on 

which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



Otterville 

Water heater load 

Palmerston 

Paris 

Water heater load 

Parkhill 

Petrolia 

Water heater load 

Plattsville 

Point Edward 

Water heater load 
Port Colborne 

Water heater load 
Port Credit 

Water heater load 
Port Dalhousie . . 

Water heater load 

Port Dover 

W 7 ater heater load 

Port Rowan 

Port Stanley 

Water heater load 
Preston 

W T ater heater load 
Princeton 



Queenston 

Richmond Hill 

Water heater load 
Ridgetown 

Water heater load 
Riverside 

Water heater load 
Rockwood 



Rodney 

Water heater load 
St. Catharines 

Water heater load 
St. Clair Beach 

Water heater load 

St. George 

St. Jacobs 

Water heater load 



$ c 
43.00 



40.00 
28.00 



62.00 
40.00 



62.00 
40.00 



28.00 
32^00 
30* 00 



40.00 



70.00 
40.00 



27.00 

55^00 

29.00 
38.00 



38.00 
33.00 
45 00 
45.00 



21.50 
38' 00 



40.00 
32.00 



$ c. 
45.00 



$ c. 
29,556.65 



40.00 
28.00 



142,824.08 
297,845.33 



62.00 
40.00 



66,838.16 
294,973.29 



55.00 
40.00 



25,549.83 
181,434.32 



29.00 
33! 00 
30 '00 



326,027.87 
146,493 !j>i 

125. 066! 91 



40.00 



103,652.03 



62.00 
40.00 



34,239.84 
117,916.25 



27.00 

50'00 

29.00 
36.00 



590,103.45 

'4 1,708' 06 

19,215.98 
87,579.54 



38.00 



33.00 



42.00 
45.00 



138,133.11 

365,935 .70 

"33,812 .94 

51.045.63 



23.00 
38 '00 



1,677,014.61 
"26. 701 .07 



42.00 
32.00 



46,499.31 
44.483.51 



74.4 

0.2 

426.0 

1,141.4 

6.5 

123.6 

841.4 

1.7 



58. 

598 



1,236 

1 

509 

8 

478 

2 



308.0 

0.4 

64.8 

354 

2 

2,317.5 

1 

108 



80.5 

285.9 

2.8 

416.9 

3.0 

,109.9 

13.6 

90.6 

126.0 





7,787 

7 

73 



139 

150 



0.6 



$ c. 
644.69 



3,691 
9,890 


38 
46 


1,071.02 
7,290.91 


504 
5,186 


31 

12 


10,712 


79 


4,411 


45 


4,147 


17 


2,668 


88 


561 
3,075 


51 

28 


20,081 


61 



940.17 

697.55 

2.477.38 



3,612 


52 


9,617 


52 


785 
1,091 


07 

$2 


67,483 


.73 


639 


49 


1,207 
1,301 


06 
51 



$ c. 

1,168.30 

♦9.62 

5,913.61 

7,543.94 

*190.13 

2,503.14 

8,812.17 

*65.35 

1,032.45 
7.474.57 

♦11.46 
6,882.69 

♦51.43 

5,391.31 

♦285.77 

4,034.79 

♦77.96 



2,677 

♦14 

1,212 

3,691 



♦80 . 1 1 

14,367.80 

♦48.12 

1,689.74 

598 . 73 

1,570.56 

♦87.83 

4,687.34 

*116.71 

7,745.21 

♦470.72 

1,077.30 

2,049.76 

♦4.93 

35,020.25 

♦187.36 

786.90 

♦4.05 

1,844.40 

1,550.46 

♦21.31 



$ c. 
1,448.44 



7,066.50 
15,034.92 



3,210.62 
14,516.75 



1,235.66 
9,113.60 



16,591.23 
' 7,403 '. 53 
"6,348! 79 



5,172.47 



1,660.56 
5,841.61 



29,674.03 

' 2,062 '. 55 

983.37 
4,419.89 



6,856.71 
18,306.73 



1,657.39 
2,506.29 



87,042.16 
"l'.322.23 



2,308.17 
2.228.10 



♦Heater costs written off in year to extent of revenue available from heater loads. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



65 



SYSTEM 



N.— COST OF POWER 



Municipality as the Cost — under Power Commission Act — of Power supplied to it 
reserve of the system and proportionately applied in reduction of such 
Municipality; and the amount remaining to be credited or 
supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Sinking 
fund 



Total 

cost of 

power 

for year 



Amount 
appropriat- 
ed from 
contingency 
reserve 
and pro- 
portionate- 
ly applied 
in reduc- 
tion of such 
cost 



Amounts 

charged 

to each 

municipality 

in respect 

of power 

supplied 

to it in 

the year 



Amounts 




received 


Amounts remaining 


from 


to be credited 


(or billed 


or charged to each 


against) 


municipality 


each 




municipality 




by the 




, 


Commission 


Credited Charged 



$ c. 
294.31 



1,273.91 
2,187.44 



753.65 
2,690.79 



266.98 
1,488.24 



2,478.68 

1, 177^55 

932.22 



939.88 



384.23 
1,057.82 



4,211.53 

'408.87 

133.20 
682.53 



$ c. 
284.35 



1,346.44 
2,724.65 



658.62 
2,802.76 



248.05 
1,694.76 



2,987.48 
1,358 '. 93 
1 ,136 .30 



980.66 



337.23 
1,114.59 



5,374.28 

"400.05 

173.33 
818.35 



1,217.79 


1,303.77 


3,176.57 


3,454.10 


326.39 
513.28 


323.35 
492.39 


9,952.14 


14,827.83 


246.75 


254.61 


419.20 
366.12 


439.41 
414.21 



$ 


c. 


3,840 


09 


9 


62 


19,291 


84 


37,381 


41 


190 


13 


8,197 


05 


36,113 


38 


65 


35 


3,287 


45 


24,957 


29 


11 


46 


39,652 


87 


51 


43 


19,742 


77 


285 


77 


16,599 


27 


77 


96 


12,439 


76 


14 


76 


4,155 


82 


14,780 


69 


80 


11 


73,709 


25 


48 


12 


5,501 


38 


2,586 


18 


9,968 


71 


87 


83 


17,678 


13 


116 


71 


42,300 


13 


470 


72 


4,169 


50 


6,653 


54 


4 


93 


214,326 


11 


187 


36 


3,249 


98 


4.05 


6,218 


24 


5,860 


40 


21 


31 



$ c. 
260.40 



1,491.00 
3,994.90 



432.60 
2,944.90 



203 . 70 
\ 2,094.75 



4,327.05 



1,781.85 
1,675. io 



1,078.00 



226.80 
1,242.15 



1 8,111.25 

"379 '.75 

281.75 
\ 1,000.65 

/ 



1,459.15 



3,884.65 



317.10 

\ 441.00 
27,257.65 



258.30 



487.55 
525.70 



$ c. 

3,579.69 

9.62 

17,800.84 

33,386.51 

190.13 

7,764.45 

33,168.48 

65.35 

3,083.75 

22,862.54 

11.46 

35,325.82 

51.43 

17,960.92 

285.77 

14,924.17 

77.96 

11,361.76 

14.76 

3,929.02 

13,538.54 

80.11 

65,598.00 

48.12 

5,121.63 

2,304.43 

8,968.06 

87.83 

16,218.98 

116.71 

38,415.48 

470.72 

3,852.40 

6,212.54 

4.93 

187,068.46 

187.36 

2,991.68 

4.05 

5,730.69 

5,334.70 

21.31 



$ c 
3,421 04 

17,470.53 
33,035.85 

7,851.52 
35,558.87 



3,342.15 
24,500.75 

36,635.66 

17,418.80 

14,812.26 

12,651.82 

4,223.02 
14,639.11 

64,424.94 

5,642.45 

2,393.63 
10,774.90 




5,946.36 
4,959.98 



87.07 
2,325 04 



258.40 
1,626.75 

1.258.41 



1,275.30 

294.00 
1,020.46 



520.82 

89.20 
1,719.01 

41.96 



103.47 



215.67 



$ c. 
168 27 

330 31 
540 . 79 



827.89 
189.87 



1,221.18 



732.20 



388.35 

5,056.45 

109.04 



396.03 



166 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the amount chargeable (upon annual adjustment) to each 

by the Commission; the amount appropriated from the contingency 

cost; the amount received by the Commission from each 

charged to each Municipality in respect of power 



Municipality 



Interim rates 

per 
horsepower 
collected by 
Commission 
during year 



To 

Jan. 1 

1933 



To 

Oct. 31 

1933 



Share of 
capital cost 
of system on 

which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of 


operating 


Operating, 




main- 




tenance 


Interest 


and 


(including 
exchange) 


adminis- 


trative 




expenses 





St. Marys 

Water heater load 
St. Thomas 

Water heater load 
Sandwich 

Water heater load 
Sarnia 

Water heater load 
Scarboro twp 

Water heater load 

Seaforth 

Simcoe 

Water heater load 
Springfield 

Water heater load 

Stamford twp 

Stouffville 

Water heater load 

Stratford 

Water heater load 
Strathroy 

Water heater load 

Sutton 

Tavistock 

Tecumseh 

Water heater load 



Thamesford 

Water heater load 
Thamesville 

Water heater load 

Thedford 

Thorndale 

Thorold 

Water heater load 

Tilbury 

Water heater load 
Tillsonburg 

Water heater load 
Toronto 

Water heater load 
Toronto twp 

Water heater load. 
Walkerville 

Water heater load. 



$ c 
34.00 



$ c 
34.00 



28.00 
32.00 



28.00 
32.00 



34.00 
32' 00 



34.00 
32'00 



35.00 
31.00 



35.00 
31.00 



48.00 



48.00 



21.00 
47.00 



21.00 
46.00 



30.00 



30.00 



34.00 



34.00 



60.00 
36.00 
37.00 



55.00 
37.00 
37.00 



40.00 
40.00 



40.00 
42.00 



72.00 
65.00 
25.00 



72.00 
65.00 
25.00 



38.00 
33.00 



38.00 
33.00 



26.10 
32.00 
28.00 



26.10 
32.00 

28.00 



$ c. 
381,531.43 



,400,461.44 
871,576.59 



2,180,312.41 
778,069 . 1 1 



141,261.98 
401,859.70 



32,461.64 



323,184.74 
66,998.67 



1,771,628.35 



259,714.56 



75,446.90 

147,072.54 

99,154.83 



50,370.02 
5 1,504 '85 



39,165.84 

21,828.02 

406,622.06 



122,347.31 
245,130.88 



62,399,625 24 
429,947 '.25 

1,95 8,828 '80 



1,287 

1 

5,477 

79 

2,795 



23.0 



7,106.4 

14.6 

2,609.8 

22.5 



447.4 

1,457.0 

3.2 

74.7 

0.2 

1,640.4 

177.2 

0.4 

6,570.9 

29.9 

886.1 

3.3 

166.6 

468.1 

281.8 

2.4 

151.0 

0.3 

158.5 

0.1 

71.0 

42.3 

1,786.1 

2.0 

364.6 

0.5 

803.8 

1.7 

243,637.2 

491.7 

1,553.1 

14.8 

6,937.1 

53.2 



$ c. 
11,159.91 



47,463 


65 


24,223 


29 


61,578 


40 


22,614 


45 


3,876 
12,625 


81 
20 


647 


29 


14,214 
1,535 


40 
47 


56,938 


18 


7,678 


24 


1,443 
4,056 
2,441 


62 
19 

85 


1,308 


45 


1,373 


43 


615.23 

366.54 

15,476.92 


3,159 


33 


6,965 


09 


2,111,165 


76 


13,457 


93 


60,111 


40 



$ c. 
14,714.42 
*43.81 
33,649.95 
*2,260.84 
17,556.07 

♦749.43 
53,006.87 

♦484.50 
15,956.34 

♦638.37 

4,629.84 
9,399.93 

*97.05 
1,147.86 

*10. 03 
6,851.89 
2,659.25 

*18.38 

47,126.61 

*908 . 42 

6,659.11 

♦107.20 

2,942.92 

4,646.14 

2,617.52 

♦92.30 

2,072.47 

♦12.46 

2,090.76 

♦4.04 

1,634.08 

1,041.78 

9,193.55 

♦51.32 

4,213.01 

♦19.71 

6,515.49 

♦57.62 

,074,540.53 

♦13,072.83 

12,364.36 

♦449.57 

37,531.72 

♦1,572.22 



$ c. 
19,048.75 



71,202 


95 


43,669 


04 


109,277 


50 


39,302 


60 


6,932 
20,434 


30 
97 


1,568 


02 


17,050 
3,312 


66 
10 


89,167 


37 


13,015 


23 


3,693 
7,322 
4,921 


38 
64 
60 


2,491 


05 


2,554 


60 


1,884 

1,039 

21,151 


65 

47 
01 


6,032 


63 


12,217 


02 


3,177,443 


27 


21,873 


62 


98,584 


12 



♦Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



167 



SYSTEM 



N.—COST OF POWER 



Municipality as the Cost — under Power Commission Act — of Power supplied to it 
reserve of the system and proportionately applied in reduction of such 
Municipality; and the amount remaining to be credited or 
supplied to it in the year ending October 31, 1933 



costs and fixed charges 


Total 

cost of 

power 

for year 


Amount 
appropriat- 
ed from 
contingency 
reserve 
and pro- 
portionate- 
ly applied 
in reduc- 
tion of such 
cost 


Amounts 

charged 

to each 

municipality 

in respect 

of power 

supplied 

to it in 

the year 


Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 




Renewals 


Sinking 
fund 


Amounts remaining 

to be credited 

or charged to each 

municipality 




Credited 


Charged 


$ c. 
3,052.66 


$ c. 
3,552.34 


$ c. 

51,528.08 

43.81 

175,136.37 

2,260.84 

100,872.21 

749.43 

262,320.98 

484.50 

91,032.59 

638.37 

17,967.88 

49,286.62 

97.05 

4,009.00 

10.03 

42,617.31 

8,761.86 

18.38 

222,636.93 

908.42 

31,885.03 

107.20 

9,577.71 

18,653.00 

11,823.91 

92.30 

6,800.15 

12.46 

6,951.53 

4.04 

4,959.85 

2,904.90 

52,080.27 

51.32 

15,646.86 

19.71 

30,056.62 

57.62 

7,330,271.64 

13,072.83 

54,988.39 

449.57 

. 229,290.91 

1,572.22 


$ c. 
\ 4,507.65 


$ c. 

47,020.43 

43.81 

155,965.12 

2,260.84 

91,087.96 

749.43 

237,448.58 

484.50 

81,898.29 

638.37 

16,401.98 

44,187.12 

97.05 

3,747.55 

10.03 

36,875.91 

8,141.66 

18.38 

199,638.78 

908.42 

28,783.68 

107.20 

8,994.61 

17,014.65 

10,837.61 

92.30 

6,271.65 

12.46 

6,396.78 

4.04 

4,711.35 

2,756.85 

45,828.92 

51.32 

14,370.76 

19.71 

27,243.32 

57.62 

6,477,541.44 

13,072.83 

49,552.54 

449.57 

205,011.06 

1,572.22 


$ c. 
1 44,964.58 

1 159,817.15 

{ 92,811.38 

\ 248,806.30 

/ 

\ 86,602.88 

16,085.54 
) 46,479.50 

\ 3,693.79 

/ 

35,400.11 
\ 8,409.03 

\ 203,303.57 

/ 

\ 31,023.05 

/ 

9,499.60 

17,680.64 

\ 10,801.42 

\ 6,208.10 

/ 

\ 6,758.77 

f 

5,208.48 
2,813.89 

1 45,918.60 

/ 

) 14,226.27 
\ 27,331.67 
16,371,763.17 
\ 51,474.89 
j 201, 601. 30 


$ c. 


$ c. 
2,099.66 


1,591.19 

973.99 

10,873.22 

4,066.22 


10,034.36 


12,785.46 


\ 19,171.25 
J 








7,250.61 


8,173.20 


\ 9,784.25 
/ 








18,061.22 


20,396.99 


\ 24,872.40 
/ 




5,912.34 


7,246.86 


\ 9,134.30 








1,206.86 


1,322.07 
3,707.44 


1,565.90 
1 5,099.50 


316.44 


3,119.08 


2,195.33 








333.45 


312.38 


1 261.45 
/ 


63 79 








1,688.47 


2,811.89 
641.14 


5,741.40 
\ 620.20 


1,475 80 


613.81 


248.99 

2,756.37 

2,132.17 

504.99 
665.99 




13,178.90 


16,225.87 


\ 22,998.15 
{' 3,101.35 








2,117.31 


2,415.14 








763.89 


733.90 

1,375.87 

942.75 


583.10 

1,638.35 

\ 986.30 

1 528.50 




1,252.16 
900 . 19 


128 49 








452.35 


475.83 




76 01 




357.95 

497.13 
57.04 
38.36 




447.76 


484.98 


1 554.75 








439.94 


385.95 

214.58 

3,638.10 


248.50 

148.05 

) 6,251.35 

/ 




242.53 




2,620.69 








1,086.55 


1,155.34 


\ 1,276.10 


164.20 




30.73 




2,067.60 


2,291.42 


{ 2,813.30 

1852,730.20 

/ 

\ 5,435.85 

| 24,279.85 








398,390.06 


568,732.02 


118,851.10 




1,472.78 




3,325.46 


3,967.02 








14,930.93 


18,132.74 


4,981 98 









68 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the amount chargeable (upon annual adjustment) to each 

by the Commission; the amount appropriated from the contingency 

cost; the amount received by the Commission from each 

charged to each Municipality in respect of power 



Municipality 



Interim rates 

per 
horsepower 
collected by 
Commission 
during year 



To 

Jan. 1 
1933 



To 

Oct. 31 

1933 



Share of 
capital cost 
of system on 

which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of 


operating 


Operating, 




main- 




tenance 


Interest 


and 


(including 


adminis- 


exchange) 


trative 




expenses 





Wallaceburg 

Water heater load. 

Wardsville 

Waterdown 

Waterford 

Water heater load. 
Waterloo 

Water heater load 

Watford 

Water heater load 
Welland 

W 7 ater heater load 

Wellesley 

West Lome 

Weston 

Water heater load 

Wheatley 

Water heater load 
Windsor 

Water heater load 
Woodbridge 

W 7 ater heater load 
Woodstock 

Water heater load 
Wyoming 



York East twp. . . . 

Water heater load 
York North twp . . . 

Water heater load 
Zurich 



$ c. 
36.00 



60.00 
34.00 
32.00 



27.00 



55.00 
23' 00 



45.00 
40.00 
28.00 



51.00 
28.00 
35.00 
27.00 
54.00 
32.00 
32.00 
62.00 



$ c. 
36.00 



62.00 
32.00 
32.00 



27.00 



55.00 
24.00 



50.00 
40.00 
27.00 



$ c. 
536,888.73 



15,388.76 

59,051.71 

108,813.44 



779,764.29 



81,608.70 
805" 460 .13 



42,384.44 

33,606.54 

624,411.23 



50.00 
28.00 
35.00 
27.00 
'56.00 
32.00 
32.66 
'62.00 



Toronto Transportation Comm 

Sandwich, Windsor and Amherst- 

burg Railway Co 

Windsor, Essex and Lake Shore 

Railway Association 



58,482.83 

5 ,'614,408. 38 

"90,450.77 

1,197,647 '85 

"28,007 .53 

1,255,879.25 

"718',868'.37 

' "37.688.IO 

93,886.13 

753,852.03 

5,306.50 



1,599.1 

1.5 

31.4 

200.3 

376.4 

0.6 

2,972.8 

19.2 

185.4 

0.4 

3,578.5 

18.8 

104.3 

99.7 

2,480.3 

24.0 

120.3 

0.7 

19,926.6 

148.7 

292.9 

0.7 

4,543.0 

21.8 

61.2 

4,883.1 
14.0 

2,490.9 
29.9 
70.0 

335.8 

2,617.5 



$ c. 
13,856.53 



272.09 
1,735.64 
3,261.58 



25,759.92 



1,606.53 
31, 008 .43 



903.78 

863.92 

21,492.30 



1,042.42 

172,668 .05 

" 2,538.04 

39,366.02 

"530.31 

42,313.05 

21,584. i6 

606.56 

2,909.78 

22,681.19 



$ 

15,236. 

*56. 

712. 

1,517 

2,570 

*18 

18,102 

*554. 

2,848 
*20 

15,801 
*463 
1,775 
1,309. 

13,060. 
*654. 

1,755. 

*37. 

105,468. 

*4,368. 

2,415. 

*24. 

26,888. 

*628. 

978. 

48,399. 

*451. 
19,312. 

*862. 

1,622. 

3,023. 

14,376 

106 



c. 

82 
18 
64 
32 
68 
95 
97 
48 

75 
31 
84 
42 
05 
62 
95 
41 

.51 

.37 
.55 
81 
68 
03 
82 
12 
50 

06 
97 
73 
06 
06 

24 

72 
18 



$ c. 
26,540.09 



745.50 
2,939.41 
5,478.83 


39,525 


10 


3,973 


75 


41,559 


71 


2,051 

1,591 

31,721 


10 
62 
02 


2,846 


46 


282,389 


.10 


4,513 


.01 


60,715 


.17 


1,358 
64,534 


.50 

.53 


36,609.90 



1,799.67 

3,952.48 

38,109.48 

182.99 



*Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



69 



SYSTEM 



N.—COST OF POWER 



Municipality as the Cost — under Power Commission Act — of Power supplied to it 
reserve of the system and proportionately applied in reduction of such 
Municipality; and the amount remaining to be credited or 
supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Sinking 
fund 



Total 
cost of 

power 
for year 



Amount 
appropriat- 
ed from 
contingency 
reserve 
and pro- 
portionate- 
ly applied 
in reduc- 
tion of such 
cost 



Amounts 

charged 

to each 

municipality 

in respect 

of power 

supplied 

to it in 

the year 



Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 



Amounts remaining 
to be credited 

or charged to each 
municipality 



Credited 



Charged 



$ c. 
4,779.30 



166.00 
488.39 
880 . 73 



5,736.44 



840.96 
5,174'61 



426.67 

304.38 

4,355.10 



626.61 



42,704.62 
' 764^75 



8,859.81 
' 294^00 
8,063.15 



5,325.23 

' 424 '89 

735.59 

5,855.03 

79.56 



$ c. 
5,076.84 



150.35 

549.40 

1,010.39 



7.138.18 



791.71 



7,191.72 



408.68 

318.18 

5,681.01 



572.56 
51,956.58 



846 . 70 
10,966.95 



272.86 
11,453.87 



6,664.05 

"37l'64 

867.48 

6,997.19 

55.85 



$ c. 

65,489.58 

56.18 

2,046.58 

7,230.16 

13,202.21 

18.95 

96,262.61 

554.48 

10,061.70 

20.31 

100,736.31 

' 463.42 

5,565.28 

4,387.72 

76,310.38 

654.41 

6,843.56 

37.37 

655,186.90 

4,368.81 

11,078.18 

24.03 

146,796.77 

628.12 

3,434.17 

174,763.66 

451.97 

89,496.07 

862.06 

4,824.82 

11,488.57 

88,019.61 

424.58 



$ c. 
\ 5,596.85 

J 



109.90 
701.05 
1,317.40 



\ 10,404.80 

/ 



648.90 
12,524.75 



365.05 

348.95 

8,681.05 



1 421.05 
| 69,743. 10 



1,025.15 
15,900.50 

"214.20 
17,090.85 
'8,718.15 



245.00 
1,175.30 
9,161.25 



$ c. 

59,892.73 

56.18 

1,936.68 

6,529.11 

11,884.81 

18.95 

85,857.81 

554.48 

9,412.80 

20.31 

88,211.56 

463.42 

5,200.23 

4,038.77 

67,629.33 

654.41 

6,422.51 

37.37 

585,443.80 

4,368.81 

10,053.03 

24.03 

130,896.27 

628.12 

3,219.97 

157,672.81 

451.97 

80,777.92 

862.06 

4,579.82 

10,313.27 

78,858.36 

424.58 



$ 
59,237 

1,979 

6,655 

12,390 



\ 72,215.25 



10,470.22 
88,102.59 



5,249 

4,089 

69,926 




43.17 
126.04 
486.71 



1,037.1 



49.34 

50.81 

1,642.37 



475.00 



269.47 
2,353.09 
1,244.66 



359.71 



$ c. 
711.90 



14,197.04 



572.39 



219.96 
8,015.38 



4,667.50 



127.04 



170 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the amount chargeable (upon annual adjustment) to each 

by the Commission; the amount appropriated from the contingency 

cost; the amount received by the Commission from each 

charged to each Municipality in respect of power 



Rural power district 



Share of 
capital cost 
of system on 

which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



Acton R.P.D. — Erin, Esquesing 
and Nassagaweya twps 

Ailsa Craig R.P.D.— Lobo, McGil- 
livray and Williams E. twps. . . . 

Alvinston R.P.D. — Brooke twp. . . 

Amherstburg R.P.D. — Anderdon, 
Colchester N., Colchester S. and 

Maiden twps 

Water heater load 

Aylmer R.P.D. — Bayham, Dere 

ham, Dorchester N., Dorchester 

S., Malahide and Yarmouth twps. 

Water heater load 

Ayr R.P.D. — Blenheim, Dumfries 

N. and Dumfries S. twps 

Baden R.P.D.— Blandford, Blen- 
heim, Easthope N., Easthope S., 
Waterloo, Wellesley, Wilmot and 

Zorra E. twps 

Water heater load 
Beamsville R.P.D. — Caistor, Clin- 
ton, Gainsborough, Grimsby N., 
Grimsby S., Louth, Pelham and 

Wainfleet twps 

W T ater heater load 
Belle River R.P.D.— Maidstone and 

Rochester twps 

Water heater load 
Blenheim R.P.D.— Raleigh and 

Harwich twps 

Water heater load 

Bond Lake R.P.D.— King, Mark- 
ham, Vaughan, Whitchurch and 

York N. twps 

Water heater load 

Bothwell R.P.D.— Aldborough.Ek- 
frid, Mosa, Orford and Zone twps. 

Brampton R.P.D. — Chinguacousy 

and Toronto twps 

Water heater load 

Brant R.P.D.— Blenheim, Brant- 
ford, Burford, Dumfries S., Oak- 
land and Onondaga twps 

Water heater load 

Brigden R.P.D. — Moore and Som- 
bra twps 



$ c. 

3,104.79 

2,210.48 
2,618.61 

181,730.18 



77,966.32 



12,056.11 



101,853.72 



303,243.58 
76,058.56 
36,427.54 



274,590.50 



36,758.70 
32,509.88 



117,042.00 
18,577.48 



10.0 

5.6 

3.2 



525.8 
1.4 



240.0 
0.2 



42.5 



345.7 
0.5 



1,058.3 

2.7 

231.0 
0.3 

108.0 
0.2 



823.9 
1.4 

94.8 

119.5 
0.1 



437.6 
1.1 

34.9 



$ c. 
86.65 

48.52 

27.73 

4,556.18 



2,079.64 



368.28 



2,995.56 



9,170.38 



2,001.68 
935.84 



7,139.26 



821.46 
1,035.49 



3,791.89 



302.421 



$ c. 

81.09 

70.68 
82.53 



$ c. 

156.29 

109.76 
125.04 



4,264.16 
*49. 38 


9,029.26 


2,048.85 
*7.16 


3,882.98 


365.40 

2,560.46 

*16.61 


611.57 
5,149.91 


9,265.10 
*90.36 


15,312.80 


2,079.52 
*11.00 


3,785.01 


934.53 

*7.35 


1,807.62 


4,822.34 
*52.29 


13,748.87 


1,158.35 

1,448.57 
*3 .57 


1,802.30 
1,652.62 


3,884.31 
*35.85 


5,963.95 


507.01 


896.40 



*Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



171 



SYSTEM 



N.—COST OF POWER 



Municipality as the Cost — under Power Commission Act — of Power supplied to it 
reserve of the system and proportionately applied in reduction of such 
Municipality; and the amount remaining to be credited or 
supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Sinkinj 
fund 



Total 
cost of 

power 
for year 



Amount 
appropriat- 
ed from 
contingency 
reserve 
and pro- 
portionate- 
ly applied 
in reduc- 
tion of such 
cost 



Amounts 

charged 

to each 

municipality 

in respect 

of power 

supplied 

to it in 

the year 



Amounts 
received 

from 

(or hilled 

against) 

each 

municipality 

by the 
Commission 



Amounts remaining 

to be credited 

or charged to each 

municipality 



Credited Charged 



$ c 

26.59 

21. 
32.69 

1,630.36 



686.82 



95.90 



834.73 



2,482.64 



659.53 
325.10 



2,299.97 



355 . 70 
248.18 



881.40 



206.79 



$ c. 

29.07 

21.22 
26.42 

,724.45 



733.70 



111.61 



947.76 



2,808.43 



717.77 
344.51 



2,592.08 



351.74 
299.17 



1,074.61 



183.04 



$ c. 

379.69 

272.06 
294.41 



21,204.41\ 
49.38/ 



9,431. 99\ 
7.16/ 



1,552.76 



12,488.42\ 
16.61] 



39,039.35\ 
90.36/ 

9,243.51) 
11.00/ 

4,347.601 

7.35/ 



30,602.52 
52.29 

4,489.55 

4,684.03\ 

3.57/ 



15,596.161 
35.85/ 

2,095.66 



$ c 

35.00 

19.60 
11.20 

1,840.30 



840.00 



148.75 



1,209.95 



3,704.05 



808.50 
378.00 

2,883.65 



331.80 
418.25 



,531.60 
122.15 



$ c 

344.69 

252.46 
283.21 



19,364.11 
49.38 



8,591.991 
7.16/ 



1,404.01 



11,278.471 
16.61/ 



35,335.301 
90.36/ 

8,435.01 
11.00 

3,969.601 
7.35/ 



27,718.871 

52.29/ 

4,157.75 

4,265.781 

3.57J 



14,064.561 

35.85/ 

1,973.51 



$ c. 


$ c. 


344.69 


see page 


252.46 
283.21 


u 

11 


19,413.49 


<< 


8,599.15 


a 


1,404.01 


' 


11,295.08 


a 


35,425.66 


« 


8,446.01 


« 


3,976.95 


" 


27,771.16 


a 


4,157.75 


« 


4,269.35 


a 


14,100.41 


a 


1,973.51 


a 



185 



11 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the amount chargeable (upon annual adjustment) to each 

by the Commission; the amount appropriated from the contingency 

cost; the amount received by the Commission from each 

charged to each Municipality in respect of power 



Rural power district 



Share of 
capital cost 
of system on 

which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of 


operating 


Operating, 




main- 




tenance 


Interest 


and 


(including 


adminis- 


exchange) 


trative 




expenses 





Burford R.P.D.— Brantford, Bur- 
ford, Oakland, Townsend and 
Windham twps 

Caledonia R.P.D. — Ancaster, Bar- 
ton, Binbrook, Caistor, Gland- 
ford, Grimsby S. f Oneida, Onon- 
daga and Seneca twps 

Water heater load 

Chatham R.P.D. — Chatham, 
Dover E., Harwich and Raleigh 

twps 

Water heater load 

Chippawa R.P.D. — Bertie, Crow- 
land and Willoughby twps 

Water heater load 

Clinton R.P.D.— Goderich, Hay, 
Hullett, Stanley and Tuckersmith 
twps 



Delaware R P.D. — Caradoc, Dela- 
ware, Ekfrid, Lobo, London, 
Southwold and Westminster twps. 
Water heater load 
Dorchester R P.D. — DorchesterN., 
Dorcheste S., London, Nissouri 
E., Nissouri W., Oxford N., West- 
minster and Yarmouth twps 

Water heater load 
Dresden R.P.D. — Camden, Chath- 

ham Gore and Dawn twps 

Water heater load 
Drumbo R.P.D.— Blandford, Blen- 
heim and Burford twps 

Dundas R.P.D. — Ancaster, Bever- 
ly, Flamboro W., Flamboro E., 

Glanford and Nelson twps 

Water heater load 

Dunnville R.P.D. — Canborough, 

Dunn and Moulton twps 

Dutton R.P.D.— Aldborough and 

Dunwich twps 

Water heater load 
Elmira R.P.D.— Peel, Pilkington 

and W 7 oolwich twps 

Water heater load 



% c. 
46,086.19 

79,953.94 



114,530.24 
21,842.34 



42,317.15 



80,489.11 



90,019.08 
13.270.82 



30,099.88 
139,904.37 



12,202.61 
38,951.00 



25,736.54 



154.3 



274.2 
0.8 



403.4 
2.4 

95.5 
0.1 



116.2 



277.8 
2.2 



290.0 
0.1 

35.9 
0.4 

75.6 



538.5 
0.7 



42.0 

118.4 
0.1 

79.9 
0.2 



$ c. 
1,337.04 

2,375.99 



3,495.54 
827.52 



1,006.90 



2,407.20 



2.512.91 



311.08 

655.09 

4,666.22 



363.94 
1,025.97 



692.35 



$ c 
1,180.55 



2,030.44 
*26.41 



2,763.43 
*74.80 

458.84 
*2.52 



1,504.21 



,889.76 
♦69.37 



2,512.71 
♦3.39 

435.46 
*17 . 13 

1,092.08 



2,339.99 
♦18.75 



208.10 

1,320.52 
♦3.64 

572.51 
♦6.89 



$ c 
2,333.79 

4.044.07 



5,776.23 
1,111.51 



2,098.24 



4,037.79 



4,474.21 



661.61 
1,469.23 
7,137.19 



622 52 
1,957 84 



1,298.99 



♦Heater costs written off in year to extent of revenue available from heater loads. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



73 



SYSTEM 



N.—COST OF POWER 



Municipality as the Cost — under Power Commission Act — of Power supplied to it 
reserve of the system and proportionately applied in reduction of such 
Municipality; and the amount remaining to be credited or 
supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Sinking 
fund 



Total 
cost of 

power 
for year 



Amount 










appropriat- 


Amounts 


Amounts 




ed from 


charged 


received 


Amounts remaining 


contingency 


to each 


from 


to be credited 


reserve 


municipality 


(or billed 


or charged to each 


and pro- 


in respect 


against) 


municipality 


portionate- 


of power 


each 




ly applied 


supplied 


municipality 




in reduc- 


to it in 


by the 






tion of such 
cost 


the year 


Commission 


Credited 


Charged 



383.25 



653.55 



890.38 
143.70 



397.87 



646.98 



769.87 



125.55 



300.45 
1,030.96 



101.75 

347.08 



225.85 



429.78 



741.57 



1,059.41 
195.59 



402.64 



745.37 



844.42 



126.79 



289.68 
1,279.03 



113.35 
367.75 



242.17 



5,664.41 



9,845.62) 
26.41/ 



13,984.99\ 
74.80/ 

2,737.16) 

2.52/ 



5,409.86 



9,727. 10\ 
69.37 f 



11,114.12 
3.39 

1,660.49 
17.13 

3,806.53 



16,453.39 
18.75 



1,409.66 

5,019.16 
3.64 

3,031.87) 
6.89/ 



540.05 



959 . 70 



1,411.90 



334.25 



406.70 



972.30 



1,015.00 



125.65 

264.60 

1,884.75 



147.00 
414.40 



279.65 



5,lz4.36 



,885. 92\ 
26.41 



12,573.09 
74.80 

2,402.91 

2.52 



5,003.16 



1, 754.80) 
69.37/ 



10,099.12) 
3.39/ 

1,534. 84\ 
17.13/ 

3,541.93 



14,568.64) 

18.75/ 



1,262.66 

4,604.76) 
3.64/ 

2,752.22) 
6.89/ 



$ c. 


$ c. 


5,124.36 


see page 


8.912.33 


« 


12,647.89 


a 


2,405.43 


u 


5,003.16 


u 


8,824.17 


a 


10,102.51 


a 


1,551.97 


see page 


3,541.93 


« 


14,587.39 


a 


1,262.66 


a 


4,608.40 


" 


2,759.11 


u 



185 



187 



74 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the amount chargeable (upon annual adjustment) to each 

by the Commission; the amount appropriated from the contingency 

cost; the amount received by the Commission from each 

charged to each Municipality in respect of power 



Rural power district 



Share of 
capital cost 
of system on 

which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



Elora R.P.D.— Garafraxa W\, 

Nichol, Peel and Pilkington twps. 

Water heater load 


$ c. 
32,226.45 


95.0 
0.1 

181.0 
0.1 

266.4 
0.2 

32.5 

173.5 

114.7 
0.3 

79.1 

633.2 
1.9 

376.7 
2.5 

188.9 
16.9 

341.5 
1.9 

323.5 
1.0 


$ c. 
823.20 


$ c. 

837.64 
♦3.63 

1,266.55 

♦3.47 

3,204.10 

*8.72 

449.21 

2,138.64 

964.15 
♦10.99 

1,120.68 

4,030.59 
*50.85 

2,582.65 
*82.34 

2,562.94 
297.74 

2,980.49 
*73.46 

3,092.39 
♦31.82 


$ c. 
1,602.43 


Essex R. P. D— Colchester N., Gos- 
field N., Gosfield S., Maidstone, 
Mersea, Rochester and Sandwich 
S. twps 


59,990.02 
103,284.53 


1,568.40 


2,984.28 


Water heater load 




Exeter R.P.D.— Biddulph, Bosan- 

quet, Hay, Hibbert, Stephen, 

Tuckersmith and Usborne twps.. 

Water heater load 


2,308.41 


5,098.93 


Forest R.P.D. — Adelaide, Bosan- 
quet, Plympton, Warwick and 
Williams W. twps 


14,085.03 
45,794.00 
38,627.01 


281.61 

1,503.41 

993.90 


691.84 


Gait R.P.D.— Beverly, Dumfries 
N. and Dumfries S. twps 

Georgetown R.P.D. — Chingua- 

cousy, Erin and Esquesing twps. 

Water heater load 


2,337.00 
1,929.60 


Goderich R.P.D.— Ashfield, Col- 
borne, Goderich and Wawanosh 
W. twps 


38,163.81 
152,577.90 


685.42 
5,486.81 


1,860.08 


Grantham R.P.D. — Grantham and 
Niagara twps 


7,862.13 


Guelph R.P.D. — Eramosa, Guelph, 
Nassagaweya and Puslinch twps. 


110,130.92 


3,264.19 


5,595.00 


Haldimand R.P.D.— Cayuga N., 
Oneida, Rainham, Seneca and 
Walpole twps 


71,822.50 
6,937.15 

122,159.62 


1,636.87 
146.44 

2,959.17 


3,535.78 


Harriston R.P.D. — Howick and 
Minto twps 

Harrow R.P.D.— Colchester N., 
Colchester S., Gosfield S. and 
Maiden twps 


342.15 
6,088.41 


Ingersoll R.P.D.— Dereham, Dor- 
chester N., Nissouri E., Oxford 
N., Oxford W., Zorra E. and Zorra 

\Y. twps 

Water heater load 


103,967.57 


2,803.19 


5,200.00 



♦Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



75 



SYSTEM 



N.— COST OF POWER 



Municipality as the Cost — under Power Commission Act — of Power supplied to it 
reserve of the system and proportionately applied in reduction of such 
Municipality; and the amount remaining to be credited or 
supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Sinking 
fund 



Total 
cost of 

power 
for year 



Amount 
appropriat 

ed from 
contingency 
reserve 
and pro- 
portionate- 
ly applied 
in reduc- 
tion of such 
cost 



Amounts 

charged 

to each 

municipality 

in respect 

of power 

supplied 

to it in 

the year 



Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 



Amounts remaining 
to be credited 

or charged to each 
municipality 



Credited 



Charged 



% c. 
293.66 



522.75 



$ c. 
305.05 



566.61 



1,014.69 


991.57 


144.25 


136.54 


339.54 


419.36 


350.40 


365.28 


411.21 


372.63 


1,060.01 


1,378.22 


900.23 


1,023.76 


690.80 


679.72 


69.59 


66.80 


1,120.73 


1,163.40 


907.16 


975.18 



3,861. 98\ 
3.63/ 



6,908. 59\ 

3.47/ 



12,617.70 
8.72 



1,703.45 

6,737.95 

4,603. 33\ 
10.99/ 

4,450.02 



19,817.76\ 

50.85/ 

13,365. 83\ 

82.34J 



9,106.11 
922.72 



14,312. 20\ 
73.46/ 



12,977.921 

31.82/ 



$ c. 
332.50 



633.50 



932.40 



113.75 
607.25 
401.45 



276.85 



2,216.20 



,318.45 



661.15 
59.15 

1,195.25 



1,132.25 



3,5.9.48 
3.63 



6,275.091 

3.47( 



11,685.301 
8.72/ 



1,589.70 

6,130.70 

4,201.881 
10.99/ 

4,173.17 



17,601.56 
50.85 

12,047. 38\ 

82.34/ 



,444.96 
863.57 



13,116.95 
73.46 



11,845.67 



45.671 
31.82/ 



$ c. 


$ c. 


3,533.11 


see page 


6,278.56 


a 


11,694.02 


u 


1,589.70 


a 


6,130.70 


a 


4,212.87 


a 


4,173.17 


« 


17,652.41 


« 


12,129.72 


U 


8,444.96 


a 


863.57 


U 


13,190.41 


a 


11,877.49 


a 



187 



76 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the amount chargeable (upon annual adjustment) to each 

by the Commission; the amount appropriated from the contingency 

cost; the amount received by the Commission from each 

charged to each Municipality in respect of power 



Rural power district 



Share of 
capital cost 
of system on 

which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



Jordan R.P.D. — Grantham, Louth, 

Pelham and Thorold twps 

Water heater load 

Keswick R.P.D. — Georgina, Gwil- 

limbury N. and Gwillimbury E. 

twps 

Water heater load 

Kingsville R.P.D.— Gosfield N., 

Gosfield S., Mersea and Romney 

twps 

Water heater load 

Listowel R.P.D. — Elma, Grey, 

Maryborough, Mornington, Peel, 

Wallace and Wellesley twps 



London R.P.D. — Delaware, Lobo, 
London, Nissouri W. and West- 
minster twps 

Water heater load 
Lucan R.P.D. — Biddulph, London, 
McGillivray and Stephen twps.. . 
Water heater load 
Lynden R.P.D. — Ancaster, Bev- 
erly, Brantford and Dumfries S. 

twps 

W^ater heater load 

Markham R.P.D. — Markham, 

Pickering, Scarboro, Uxbridgeand 

Whitchurch twps 

Water heater load 

Merlin R.P.D. — Raleigh, Romney 

and Tilbury E. twps 



Milton R.P.D. — Esquesing, Nassa- 
gaweya, Nelson and Trafalgar 

twps 

W 7 ater heater load 

Milverton R.P.D.— Ellice, Elma, 

Mornington and Wellesley twps.. 

Mitchell R.P.D.— Downie, Ellice, 

Elma, Fullarton, Hibbert, Logan 

and McKillop twps 

W : ater heater load 

Newmarket R.P.D. — Georgina, 

Gwillimbury E., King, Scott, Ux- 

bridge and Whitchurch twps.. . . 

Water heater load 

Niagara R.P.D. — Niagara and 

Stamford twps 

Water heater load 



« c. 
71,232.87 



156,132.01 



186,802.68 



40,298.27 



403,592.61 



17,375.23 



50,814.70 



123,874.94 
62,717.77 

45,477.32 



21,126.93 

54,581.38 



70,499.35 
77,552.95 



299.9 
1.1 



405.3 
0.1 



527.4 
2.6 



26.4 



1,394.0 
10.2 

56.2 
0.2 



159.2 
0.2 



393.7 
0.2 

159.0 



147.8 
0.1 

65.8 



169.2 
0.3 



215.7 
0.2 

346.1 
2.0 



* c. 
2,598.70 



3,512.00 



4,570.03 



1,095.28 



12,079.29 



486.99 



,379.50 



3,411.49 
1,377.77 

1,280.72 



570.17 



1,466.15 



,869.08 



2,999.02 



$ c. 

1,447.62 

*28.65 



5,489.59 

*4.22 



4,156 67 

*84.55 



1,421.62 



9,234.49 
*274.40 

526.26 
*7.11 



1,590.52 
*7.64 



3,251.39 
*7.14 

2,210.67 



1,963.19 
*3.94 

613.19 



1,399.70 
*10.73 



2,012.75 
*6.83 

2,077.39 
*52.30 



ft c. 
3,686.50 



7,737.29 



9,224.31 



2,019.93 



20,384.83 



864 


M 


2,529 


42 


6,224 


77 



3,111.42 



2,291.91 



1,058.43 
2,726.50 



3,521.46 
3,974.55 



*Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



77 



SYSTEM 



N.—COST OF POWER 



Municipality as the Cost — under Power Commission Act — of Power supplied to it 
reserve of the system and proportionately applied in reduction of such 
Municipality; and the amount remaining to be credited or 
supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Sinking 
fund 



Total 
cost of 

power 
for year 



Amount 
appropriat- 
ed from 
contingency 
reserve 
and pro- 
portionate- 
ly applied 
in reduc- 
tion of such 
cost 



Amounts 

charged 

to each 

municipality 

in respect 

of power 

supplied 

to it in 

the year 



Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 



Amounts remaining 

to be credited 

or charged to each 

municipality 



Credited 



Charged 



$ c. 
483.58 



1,447.19 



1,703.20 



346.79 



3,251.68 



146.86 



444.87 



989.08 
617.15 

385.96 



182.76 



473.79 



580.37 
496.73 



$ c. 
641.42 



1.496.7; 



1.777.33 



377.61 

3,743.82 
162.01 



476.47 



1,161.43 

604.43 

425.48 



198.13 



512.19 



663.33 



691.88 



$ c 

,857.82 

28.65 



19,682.85) 

4.22/ 



21,431. 54\ 

84.55/ 



5,261.23 



48,694. 11\ 
274.40/ 

2,186.44) 

7.11 



6,420.78) 

7.64/ 



15,038.16 
7.14 

7,921.44 



6,347.26 
3.94 

2,622.68 



6,578.33) 
10.73 



8,646.99 
6.83 

10,239.57 
52.30/ 



1,049 


c. 

65 


1,418 


55 


1,845 


90 


442 
4,879 


40 
00 


196 


70 


557 


20 


1,377 


95 


556 
517 


50 
30 


230 
592 


30 
20 


754.95 


1,211 


.35 



7,808.17) 
28.65/ 



18,264.30) 

4.22/ 



19,585.64) 

84.55/ 



4,818.83 



43,815.11) 
274.40/ 

1,989.74) 
7.11/ 



5,863.58 
7.64 



13,660.21 
7.14 

7,364.94 



5,829.96) 
3.94/ 

2,392.38 



5,986.13) 
10.73/ 



7,892.04) 
6.83/ 

9,028.22) 

52.30/ 



$ 

7,836 


c. 

82 


18,268 


52 


19,670 


19 


4,818 


83 


44,089 


51 


1,996 


85 


5,871 


22 


13,667 


35 


7,364 


94 


5,833 


90 


2,392 


38 


5,996.86 


7,898 


87 


9,080 


52 



$ c. $ c. 

see page 187 



see page 



189 



178 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the amount chargeable (upon annual adjustment) to each 

by the Commission; the amount appropriated from the contingency 

cost; the amount received by the Commission from each 

charged to each Municipality in respect of power 



Rural power district 



Share of 
capital cost 
of system on 

which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



Norwich R.P.D.— Burford, Dere- 
ham, Middleton, Norwich N., 
Norwich S., Oxford E. and Wind- 
ham twps 

Water heater load 

Oil Springs R.P.D. — Brooke, 
Dawn, Enniskillen and Euphemia 



twps 

Palmerston R.P.D. — Arthur, 
Maryborough, Minto, Peel and 
Wallace twps 

Petrolia R.P.D.— Enniskillen , 
Moore, Plympton and Sarnia twps 

Preston R.P.D.— Dumfries N., 
Guelph, Puslinch, Waterloo and 

Woolwich twps 

W^ater heater load 

Ridgetown R.P.D.— Aldborough, 
Harwich, Howard, Orford and 

Rondeau Park twps 

Water heater load 
St. Jacobs R.P.D.— Peel, Waterloo, 
Wellesley and W 7 oolwich twps. . . . 
Water heater load 
St. Marys R.P.D.— Blanshard, 
Downie, Fullarton, Nissouri E., 
Nissouri W. and Usborne twps. . . 
St. Thomas R.P.D.— Dunwich, 
Southwold, Westminster and Yar- 
mouth twps 

Water heater load 
Saltfleet R.P.D.— Barton, Bin- 
brook, Grimsby N. and Saltfleet 

twps 

Water heater load 

Sandwich R.P.D.— Anderdon, Col- 
chester N., Maidstone, Sandwich 
E., Sandwich W. and Sandwich S. 



twps 

Water heater load 
Sarnia R.P.D. — Moore, Plympton 

and Sarnia twps 

Water heater load 



$ c 



76,245.00 



15,976.46 

16,763.38 
8,745.06 

239,163.10 



95,655.14 
71,027.26 



65,182.98 
127.738.17 



264,433.70 



265,738.12 
167,396.36 



241.6 
0.6 



41.6 

50.0 

25.3 



849.0 
1.2 



244.9 
1.1 

237.6 
0.2 



185.4 



455.2 
3.2 



875.3 
1.3 



874.4 
2.4 

493.7 
2.6 



2,093.51 



360.47 

433.26 
219.23 

7,356.76 



2,122.11 



2,058.84 



1,606.53 
3,944.40 



7,584.65 



7,576.86 



4,278.01 



$ 


c. 


2,001 


28 


*20 


88 


464 


54 


615 


21 


245 


56 


5,318 
*33 


19 

78 


3,125 


96 


*48 


79 


1,828 
*6 


64 

57 


2,155 


39 


3,164 
*99 


90 
59 


6,093.66 
*36.84 


5,202 

*75 


.50 
89 


4,485 
♦96 


.74 
.93 



3,781.35 

786.05 

840 . 75 
434.63 

12,110.32 

4,689.57 
3,573.40 

3,242.36 
6,447.38 

13,201.52 

13,286.18 
8,337.84 



*Heater costs written off in year to extent of revenue available from heater loads. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



179 



SYSTEM 



N.—COST OF POWER 



Municipality as the Cost — under Power Commission Act — of Power supplied to it 
reserve of the system and proportionately applied in reduction of such 
Municipality; and the amount remaining to be credited or 
supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Sinking 
fund 



Total 

cost of 

power 

for year 



Amount 










appropriat- 


Amounts 


Amounts 




ed from 


charged 


received 


Amounts remaining 


contingency 


to each 


from 


to be credited 


reserve 


municipality 


(or billed 


or charged to each 


and pro- 


in respect 


against) 


municipality 


portionate- 


of power 


each 




ly applied 


supplied 


municipality 




in reduc- 


to it in 


by the 






tion of such 
cost 


the year 


Commission 


Credited 


Charged 



660.00 



154.00 

149.52 
79.05 

,886.91 



933.03 



589.06 



593.47 
1,004.21 



2,231.53 



2,158.49 



1,493.63 



715.79 



153.23 

158.04 
82.97 

2,211.21 



918.68 



662.17 



619.41 
1,182.08 



2,469.16 



2,479.68 



1,584.73 



9,251.931 

20.881 



1,918.29 

2,196.78 
1,061.44 



28,883. 39\ 
33.78/ 



11,789.35\ 
48.79/ 

8,712.11 
6.57 



8,217.16 



15,742.97 
99.59 



31,580.52) 
36.84/ 



30,703.71 
75.89 

20,179. 95\ 
96.93/ 



845.60 



145.60 

175.00 
88.55 

2,971.50 



857 15 



831.60 



648.90 
1,593.20 



3,063.55 



3,060.40 



1,727.95 



8,406.33 
20.88 



1,772.69 

2,021.78 
972.89 



25,911.89 
33.78 



10,932.20 
48.79 

7,880. 51\ 

6.57/ 



7,568.26 



14,149.77 
99.59 



28,516. 97\ 
36.84f 



27,643.31) 

75.89/ 

18,452. 00\ 
96.93f 



$ c 


$ c. 


8,427.21 


see page 


1,772.69 


a 


2,021.78 


a 


972.89 


u 


25,945.67 


a 


10,980.99 


u 


7,887.08 


a 


7,568.26 


» 


14,249.36 


" 


28,553.81 


u 


27,719.20 


« 


18,548.93 


a 



189 



180 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the amount chargeable (upon annual adjustment) to each 

by the Commission; the amount appropriated from the contingency 

cost; the amount received by the Commission from each 

charged to each Municipality in respect of power 



Rural power district 



Share of 
capital cost 
of system on 

which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



Scarboro R.P.D. — Pickering, Scar- 

boro and York N. twps 

Water heater load 

Seaforth R.P.D.— Hibbert, Hul- 
lett, McKillop and Tuckersmith 
twps 

Simcoe R.P.D. — Charlotteville, 
Townsend, Walpole, Windham 

and Woodhouse twps 

Water heater load 

Stamford R.P D— Stamford and 
Thorold twps 

Stratford R.P.D.— Downie, East- 
hope N., Easthope S. and Ellice 

twps 

Water heater load 

Strathroy R.P.D.— Adelaide, Cara- 
doc, Ekfrid, Lobo, Metcalfe and 
Williams E. twps 

Streetsville R.P.D.— Chingua- 
cousy, Esquesing, Toronto and 

Trafalgar twps 

W^ater heater load 

Tavistock R.P.D.— Easthope N., 
Easthope S., Ellice and Zorra E. 
twps 



Thamesville R.P.D.— Camden, 
Chatham, Euphemia, Harwich, 
Howard, Orford and Zone twps. . 
Water heater load 
Tilbury R.P.D.— Dover W\, Mer- 
sea, Rochester, Romney, Tilbury 
E., Tilbury W. and Tilbury N. 

twps 

Water heater load 
Tillsonburg R.P.D.— Bayham, 
Dereham, Dorchester S., Hough- 
ton, Malahide, Middleton, Nor- 
wich N., Norwich S. and Walsing- 

ham N. twps 

W 7 ater heater load 
Wallaceburg R.P.D.— Chatham, 

Dover E. and Sombra twps 

Water load heater 



$ c. 
99,385.27 



16,950.28 
57,483.39 



37,543.95 
40,881.40 



30,824.41 
90,613.06 



44,994.85 



31,715.30 



53,383.43 



95,102.09 



61,583.45 



300.6 
1.1 



51.7 



202.3 

2.5 



159.4 



150.7 
0.3 



89.2 



270.2 
0.6 



143.3 



97.6 
0.3 



158.0 
0.1 



290.7 
1.3 

179.6 
0.5 



$ 


c. 


2,604 


76 


447 


99 


1,752 


97 


1,381 


24 


1,305 


85 


772 


94 


2,341 


34 


1,241 


73 


845 


72 


1,369 


10 


2,518 


98 


1,556 


28 



1,677.34 
*29.82 



518.88 



1,839.38 
*83. 65 



723.64 



1,075.45 
*9.14 



1,085.28 



3,067.42 
*23.90 



1,297.06 



885.05 
*10.92 



1,566.46 
*3.82 



2,447.83 
*46.45 

1,872.84 
♦19.57 



$ c 
4,982.47 



847.97 
2,917.91 



1,934.38 
2,054.35 



1,537.58 
4,513.87 



2,246.02 



1,588.71 



2,672.49 



4,700.37 
3,042.59 



*Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



SYSTEM 



N.—COST OF POWER 



Municipality as the Cost — under Power Commission Act — of Power supplied to it 
reserve of the system and proportionately applied in reduction of such 
Municipality; and the amount remaining to be credited or 
supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Sinking 
fund 



Total 
cost of 

power 
for year 



Amount 
appropriat- 
ed from 
contingency 
reserve 
and pro- 
portionate- 
ly applied 
in reduc- 
tion of such 
cost 



Amounts 

charged 

to each 

municipality 

in respect 

of power 

supplied 

to it in 

the year 



Amounts 






received 


Amounts remaining 


from 


to be credited 


(or billed 


or charged to each 


against) 


municipality 


each 




municipality 




by the 








Commission 


Credited 


Charged 





$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ C. 




827.51 


937.54 


11,029.621 
29.82/ 

2,123.06 


1,052.10 


9,977.521 
29.82/ 

1,942.11 


10,007.34 
1,942.11 


see page 
see page 


189 




148.85 


159.37 


180.95 


191 




458.38 


532.52 


7,501.161 
83.65/ 


708.05 


6793.11/ 
83.65/ 


6,876.76 


a 


« 




252.73 


337.90 


4,629.89 


557.90 


4,071,99 


4,071.99 


a 


" 




306.03 


374.77 


5,116.451 
9.14/ 

3,970.60 


527.45 


4,589.001 
9.14/ 

3,658.40 


4,598.14 


a 


a 




282.79 


292.01 


312.20 


3,658.40 


u 


« 




817.72 


856.54 


11,596.89/ 
23.90/ 

5,588.60 


945.70 


10,651.191 
23.90/ 

5,087.05 


10,675.09 


a 


u 




382.89 


420.90 


501.55 


5,087.05 


u 


a 




275.71 


298.63 


3,893.82/ 
10.92/ 

6,588.89/ 

3.82/ 

11,404.411 
46.45/ 

7,611.431 
19.57/ 


341.60 


3,552.221 
10.92/ 

6,035.891 

3.82/ 

10,386.96/ 

46 45 r 


3,563.14 


a 


a 


476.33 


504.51 


553.00 


6,039.71 


u 


u 


842.21 


895.02 


1,017.45 


10,433.41 


u 


it 


556.02 


583.70 


628.60 


6,982.831 
19.57( 


7,002.40 


a 


u 



182 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the amount chargeable (upon annual adjustment) to each 

by the Commission; the amount appropriated from the contingency 

cost; the amount received by the Commission from each 

charged to each Municipality in respect of power 



Rural power district 



Share of 
capital cost 
of system on 

which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



Walsingham R.P.D.— Charlotte- 
ville, Houghton, Middleton, Wal- 
singham N., Walsingham S. and 

Windham twps 

Water heater load 

Walton R.P.D.— Grey, Hullett, 
McKillop, Morris, Wawanosh E. 

and Wawanosh W. twps 

Water heater load 

Waterdown R.P.D. — Flamboro E., 

Flamboro W. and Nelson twps.. . 

Water heater load 

Waterford R.P.D. — Townsend, 

and Windham twps 

Water heater load 
Watford R.P.D.— Adelaide, Met- 
calfe and Warwick twps 

Welland R.P.D.— Bertie, Crow- 
land, Humberstone, Moulton, 
Pelham, Thorold, Wainfleet, 

and Willoughby twps 

W T ater heater load 

Woodbridge R.P.D.— Albion.Chin- 
guacousy, Etobicoke, King, Tor- 
onto, Toronto Gore, Vaughan and 

York N. twps 

Water heater load 

Woodstock R.P.D.— Blandford, 
Blenheim, Burford, Oxford E., 
Oxford N., Oxford W., Zorra E. 

and Zorra W. twps 

Water heater load 



Totals Municipalities 

Water heater loads . . . 
Totals — Rural Power Districts. 

Water heater loads . . . 

Totals — Companies 

Totals — Local distribution sys- 
tems 

Water heater loads . . . 
Non-operating capital 



Grand total 



60,798.60 



35,873.12 
203,660.56 



45,907.50 
8,749.66 

262,740.63 



165,290.75 



137,723.61 



144,023,104.06 



7,289,267.28 

45,468,930' 88 

1,406,334.62 



102,132.57 



198,289,769.41 



133 




85 


651 
9 

158 


20 



1,012 
3 



525 
1 



479 
1 



552,272. 

1,851 

23,605 

76 

197,579. 

4,182. 
19. 



779,587.6 



$ c 



1,152.47 



740.87 



5,644.51 

1,376.04 

180.24 

8,770.05 



4,554.43 



4,155.83 



4,785,554.05 
'204,543 '.91 



1,712,065.60 
36,243.07 



6,738,406.63 



$ c 



1,692.29 
*24.80 



1,215.98 
*4.83 

4,376.74 
*286.45 

1,008.90 
*9.36 

273.29 



7,933.46 
*99.10 



3,631.92 
*63.68 



2,868.08 
*45.85 



2,921,649.15 

*52,502.48 

190,563.18 

*2,429.87 

974,752.47 

100,542.47 
♦628.72 



4,243,068.34 



$ c. 



2,980.25 



1,759.75 



10,195.13 

2,325.73 

431.75 

13,324.10 



,256.37 



6,929.98 



7,314,488.01 
365,513 '99 



2,399,216.15 
72,329.47 



10,151,547.62 



*Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



183 



SYSTEM 



N.—COST OF POWER 



Municipality as the Cost — under Power Commission Act — of Power supplied to it 
reserve of the system and proportionately applied in reduction of such 
Municipality; and the amount remaining to be credited or 
supplied to it in the year ending October 31, 1933 



costs and fixed charges 


Total 

cost of 

power 

for year 


Amount 
appropriat- 
ed from 
contingency 
reserve 
and pro- 
portionate- 
ly applied 
in reduc- 
tion of such 
cost 


Amounts 

charged 

to each 

municipality 

in respect 

of power 

supplied 

to it in 

the year 


Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 






Renewals 


Sinking 
fund 


Amounts reman 
to be credited 
or charged to each 
municipality 




Credited 


Charged 


$ c. 
646.45 


$ c. 
592.35 


$ c. 

7,063. 81\ 
24.80/ 

4,426.521 

4.83/ 

23,888.02\ 
286.45/ 

5,508.51/ 
9.36/ 

1,058.31 

34,410.87/ 
99.10/ 

19,412.12/ 
63.68/ 

16,336.80) 
45.85/ 


$ c. 
465.50 

299.25 
2,279.90 


$ c. 

6,598.31/ 
24.80/ 

4,127.27/ 
4.83/ 

21,608.12/ 
286.45/ 

4,952.71/ 
9.36/ 

985.51 

30,868.52/ 
99.10/ 

17,572.52/ 
63.68/ 

14,658.20/ 

45.85/ 


$ c. 
6,623.11 

4,132.10 

21,894.57 

4,962.07 

985.51 

30,967.62 

17,636.20 
14,704.05 


$ c. 
see page 

u 

a 

a 
a 


$ c. 
191 


363.79 


346.13 


u 


1,762.59 


1,909.05 


a 


371.57 


426.27 


555.80 
72.80 

3,542.35 
1,839.60 


« 


88.49 
1,981.39 


84.54 
2,401.87 


« 


1,417.98 


1,551.42 


u 


1,105.60 


1,277.31 


1,678.60 


u 








1,003,146.46 


1,317,126.56 


17,341,964.231 

52,502.48/ 

890,298.62/ 

2,429.87/ 

5,796,876.29 

241,429.89/ 
628.72/ 


1,932,954.10 

' 82,618.20 


15,409,010.13/ 

52,502.48/ 

807,680.42/ 

2,429.87/ 

5,796,876.29 

241,429.89/ 

628.72/ 


15,215,450.86 
810,110.29 

3,590,229.96 
227,670.51 


74,541.31 


320,603.06 


61,478.48 


68,199.06 










288,709.67 
23,444.26 


422,132.40 
8,870.62 




2,206,646. 33f 
14,388. 10f 




























1,376,778.87 


1,816,328.64 


24,326,130.10 


2,015,572.30 


22,310,557.80 


19,843,461.62 


74,541.31 


2,541,637.49 



fWritten off to contingency reserve. 



84 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA SYSTEM— 

Statement showing the costs of distribution of power within each Rural Power 

and the amounts remaining to be credited to certain Districts or charged 

(by annual adjustment) of the actual costs 



District and municipalities 
comprised therein 



Total capital cost of each district, 
Provincial Government grant re- 
ceived and applied thereagainst, 
and the balance representing the 
investment by the Commission 



Total 

capital 

cost 



Govern- 
ment 
grant 



Com- 
mission's 
investment 



Cost of 

power 
delivered 
to districts 
as shown 
in "cost of 

power" 

table 

preceding 



Acton R.P.D. — Erin, Esquesing and Nassa- 
gaweya twps 



Ailsa Craig R.P.D.— Lobo, McGillivray and 
Williams E. twps 

Alvinston R.P.D. — Brooke twp 

Amherstburg R.P.D. — Anderdon, Colches- 
ter N., Colchester S., and Maiden twps. . 

Aylmer R.P.D. — Bayham, Dereham, Dor- 
chester N., Dorchester S., Malahide and 
Yarmouth twps 



Ayr R.P.D. — Blenheim, Dumfries N. and 
Dumfries S. twps 

Baden R.P.D.— Blandford, Blenheim, East- 
hope X., Easthope S., Waterloo, Wellesley, 
Wilmot and Zorra E. twps 

Beamsville R.P.D. — Caistor, Clinton, 
Gainsborough, Grimsby N., Grimsby S., 
Louth, Pelham and Wainfleet twps 

Belle River R.P.D.— Maidstone and Ro- 
chester twps 

Blenheim R.P.D. — Raleigh and Harwich 
twps 



Bond Lake R.P.D. — King, Markham, 
Vaughan, Whitchurch and York N. twps. 

Bothwell R.P.D.— Aldborough, Ekfrid, 
Mosa, Orford and Zone twps 

Brampton R.P.D. — Chinguacousy and 
Toronto twps 

Brant R.P.D.— Blenheim, Brantford, Bur- 
ford, Dumfries S., Oakland and Onondaga 
twps 

Brigden R.P.D. — Moore and Sombra twps 

Burford R.P.D.— Brantford, Burford, Oak- 
land, Townsend and Windham twps. . . 

Caledonia R.P.D. — Ancaster, Barton, Bin 
brook, Caistor, Glanford, Grimsby S., 
Oneida, Onondaga and Seneca twps 

Chatham R.P.D.— Chatham, Dover E. 
Harwich and Raleigh twps 

Chippawa R.P.D. — Bertie, Crowland and 
Willoughby twps 

Clinton R.P.D.— Goderich, Hay, Hullett 
Stanley and Tuckersmith twps 



Delaware R.P.D. — Caradoc, Delaware, Ek 
frid, Lobo, London, Southwold and West 
minster twps 

Dorchester R.P.D. — Dorchester N., Dor- 
chester S., London, Nissouri E., Nissouri 
\\\, Oxford N., Westminster and Yar- 
mouth twps 



$ 


c. 


14,921 


66 


9,208 
5,447 


19 
60 


139,175 


07 


♦191,391 


87 


♦41,231 


34 


♦168,426 


20 


352,966 


94 


87,817 


60 


♦107,444 


50 


331,890 


87 


♦54,334 


84 


78,385 


00 


♦227,466 
54,675 


48 
09 


93,034 


23 


202,096 


.52 


258,017 


.35 


58,104 


.36 


126,143 


.80 



=225,463.84 



*202,777.92 



$ c. 

7,460.83 

4,604.10 

2,723.80 

69,502.03 

93,840.30 

20,580.18 

83,853.79 

170,410.90 
43,832.64 
52,732.90 

165,945.43 
26,835.40 
39,192.50 



112,622.33 
27,337.54 



46,517.11 

100,802.33 

129,008.68 

29,049.30 

62,133.13 

111,784.97 



$ c. 

7,460.83 

4,604.09 
2,723.80 

69,673.04 

97,551.57 

20,651.16 

84,572.41 

182,556.04 
43,984.96 
54,711.60 

165,945.44 
27,499.44 
39,192.50 



114,844.15 
27,337.55 



46,517.12 

101,294.19 

129,008.67 

29,055.06 

64,010.67 

113,678.87 



100,397.32 102,380.60 



$ c. 
344.69 

252.46 

283.21 

19,413.49 

8,599.15 

1,404.01 

11,295.08 

35,425.66 
8,446.01 
3,976.95 

27,771.16 
4,157.75 
4,269.35 



14,100.41 
1,973.51 



5,124.36 

8,912.33 

12,647.89 

2,405.43 

5,003.16 

8,824.17 

10,102.51 



Items marked ♦ include portions of transmission lines aggregating $44,995.90 used for 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



185 



RURAL POWER DISTRICTS N.— RURAL OPERATING 

District, the revenues collected from (or charged to) customers within each District, 
to the Municipalities comprising certain other Districts upon ascertainment 
in the year ending October 31, 1933 



Distribution 


costs and 


fixed charges 




Total 
cost 


Revenue 

from 

power 

and light 

customers 

in each 

district 


Amounts i 


'emainine: 


Cost of 
operation, 
mainten- 
ance and 
adminis- 


Interest 
(including 
exchange) 


Renewal 
charges 


Obsoles- 
cence 
and 
contin- 
gencies 


Sinking 
fund 


to be credited to 
certain districts or 
charged to the muni- 
cipalities comprising 
certain other 
districts 


tration 


Credited 


Charged 


$ c. 
363.43 


$ c. 

342.50 

212.76 
126.25 

3,163.51 

4,460.49 

940 . 85 

3,847.76 

8,324.96 
2,027.58 
2,511.95 

7,385.44 
1,319.28 
1,800.60 

5,309.03 
1,260.43 

2,119.38 

4,655.48 
5,864.93 
1,340.72 
2,865.62 

5,179.34 

4,669.84 


$ c. 

295.48 

183.55 
108.92 

2,725.81 

3,775.46 

810.27 

3,305.17 

6,942.95 
1,746.20 
2,127.54 

6,371.59 
1,124.90 
1,553.42 

4,535.79 
1,087.40 

1,828.44 

4,006.55 
5,059.80 
1,156.56 
2,434.69 

4,430.46 

3,986.24 


$ c. 

147.74 

91.78 
54.46 

1,362.91 

1,887.72 

405 . 14 

1,652.59 

3,471.47 

873.09 

1,063.78 

3,185.80 
562.45 
776.70 

2,267.90 
543 . 70 

914.22 

2,003.28 
2,529.90 

578.28 
1,217.35 

2,215.23 

1,993.12 


$ c. 

77.79 

48.32 
28.67 

718.47 

1,013.03 

213.68 

873.87 

1,890.69 
460.48 
570.50 

1,677.32 
299.62 
408.94 

1,205.74 
286.26 

481.34 

1,057.31 

1,331.99 

304.49 

650.82 

1,176.29 

1,060.58 


$ c. 

1,571.63 

961.62 
705.48 

32,042.89 

27,858.44 

5,419.70 

26,370.97 

74,316.32 
17,371.42 
14,623.21 

61,498.42 
10,508.02 
11,531.52 

36,687.56 
6,595.44 

13,977.00 

27,723.95 

39,029.04 

8,313.55 

16,441.34 

30,860.85 

30,128.48 


$ c. 

1,320.29 

887.13 
509.05 

35,200.71 

29.452.53 

4,144.44 

23,050.86 

75,426.87 
18,957.35 
17,018.78 

66,163.80 

9,997.89 

10,070.38 

31,473.27 
5,402.89 

13,597.80 

25,038.94 

38,880.56 

8,287.66 

15,169.53 

30,609.57 

30,551.38 


$ c. 


$ c 
251.34 


172.75 




74.49 


103.97 




196.43 


4,658.70 


3,157.82 
1,594.09 




8,122.59 
1,645.75 




1,275.26 


5,396.50 




3,320.11 


18,260.59 


1,110.55 
1,585.93 
2,395.57 

4,665.38 




3,818.06 




4,372.49 




15,107.11 




3,044.02 


510.13 


2,722.51 




1,461.14 


9,268.69 




5,214.29 


1,444.14 




1,192.55 


3,509.26 




379.20 


7,089.00 




2,685.01 


11,594.53 




148.48 


2,528.07 




25.89 


4,269.70 




1,271.81 


9,035.36 




25.1.28 


8,316.19 


422.90 





purposes of rural power districts. 



86 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA SYSTEM— 

Statement showing the costs of distribution of power within each Rural Power 

and the amounts remaining to be credited to certain Districts or charged 

(by annual adjustment) of the actual costs 



District and municipalities 
comprised therein 



Total capital cost of each district, 
Provincial Government grant re- 
ceived and applied thereagainst, 
and the balance representing the 
investment by the Commission 



Total 

capital 

cost 



Govern- 
ment 
grant 



Com- 
mission's 
investment 



Cost of 

power 
delivered 
to districts 
as shown 
in "cost of 

power" 

table 

preceding 



Dresden R.P.D. — Camden, Chatham Gore 
and Dawn twps 

Drumbo R.P.D. — Blandford, Blenheim and 
Burford twps 

Dundas R.P.D. — Ancaster, Beverly, Flam- 
boro W., Flamboro E., Glanford and 
Nelson twps 



Dunnville R.P.D. — Canborough, Dunn and 
Moulton twps 

Dutton R.P.D. — Aldborough and Dunwich 
twps 

Elmira R.P.D.— Peel, Pilkington and Wool- 
wich twps 

Elora R.P.D.— Garafraxa W., Nichol, Peel 
and Pilkington twps 

Essex R.P.D.— Colchester N., Gosfield N., 
Gosfield S., Maidstone, Mersea, Rochester 
and Sandwich S. twps 



Exeter R.P.D. — Biddulph, Boanquet, Hay, 

Hibbert, Stephen, Tuckersmith and Us- 

borne twps 

Forest R.P.D. — Adelaide, Bosanquet, 

Plympton, Warwick and Williams W. 

twps 

Gait R.P.D.— Beverly, Dumfries N. and 

Dumfries S. twps 

Georgetown R.P.D. — Chinguacousy, Erin, 

and Esquesing twps 

Goderich R.P.D.— Ashfield, Colborne, God- 

erich and Wawanosh W. twps 



Grantham R.P.D. — Grantham and Ni- 
agara twps 

Guelph R.P.D. — Eramosa, Guelph, Nassa- 
gaweya and Puslinch twps 

Haldimand R.P.D. — Cayuga N., Oneida, 
Rainham, Seneca and Walpole twps.... 

Harriston R.P.D. — Howick and Minto 
twps 

Harrow R.P.D. — Colchester N., Colchester 
S., Gosfield S. and Maiden twps 



Ingersoll R.P.D. — Dereham, Dorchester N., 
Nissouri E., Oxford N., Oxford W., Zorra 
E. and Zorra W. twps 

Jordan R.P.D. — Grantham, Louth, Pelham 
and Thorold twps 

Keswick R.P.D. — Georgina, Gwillimbury 
N. and Gwillimbury E. twps 

Kingsville R.P.D.— Gosfield N., Gosfield S., 
Mersea and Romney twps 

Listowel R.P.D. — Elma, Grey, Marybor- 
ough, Mornington, Peel, Wallace and 
Wellesley twps 



$ c. 

36,380.21 

*99,987.72 

241,776.43 

42,560.74 
73,501.93 
34,874.17 
83,566.33 

'140,126.10 

'143,946.40 

*60,641.77 
79,885.82 

103,742.88 
71,710.60 

145,534.40 
181,689.73 
'101,014.53 
♦32,608.18 
137,336.33 

290,124.29 

98,666.04 

163,537.51 

^288,182.64 

117,836.37 



$ c. 
18,190.11 
49,594.18 

117,420.14 

21,280.37 
36,750.97 
17,437.09 
41,564.26 

69,165.32 

71,241.52 

29,979.55 
39,942.91 
51,871.44 
35,589.59 

68,687.20 
90,814.95 
49,156.80 
16,023.93 
68,668.17 

145,062.15 
49,333.02 
79,191.31 

141,927.52 

58.918.18 



$ c 
18,190.10 
50,393.54 

124,356.29 

21,280.37 
36,750.96 
17,437.08 
42,002.07 

70,960.78 

72,704.88 

30,662.22 
39,942.91 
51,871.44 
36,121.01 

76,847.20 
90,874.78 
51,857.73 
16,584.25 
68,668.16 

145,062.14 
49,333.02 
84,346.20 

146,255.12 

58,918.19 



$ c. 
1,551.97 
3,541.93 

14,587.39 

1,262.66 
4,608.40 
2,759.11 
3,533.11 

6,278.56 

11,694.02 

1,589.70 
6,130.70 
4,212.87 
4,173.17 

17,652.41 

12,129.72 

8,444.96 

863.57 

13,190.41 

11,877.49 

7,836.82 

18,268.52 

19,670.19 

4.818.83 



Items marked * include portions of transmission lines aggregating $44,995.90 used for 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



187 



RURAL POWER DISTRICTS N.— RURAL OPERATING 

District, the revenues collected from (or charged to) customers within each District, 

to the Municipalities comprising certain other Districts upon ascertainment 
in the year ending October 31, 1933 



Distribution costs and fixed charges 




Total 
cost 


Revenue 

from 

power 

and light 

customers 


Amounts remaining 


Cost of 
operation, 

mainten 
ance and 


Interest 
(including 
exchange) 


Renewal 
charges 


Obsoles- 
cence 
and 
contin- 


Sinking 
fund 


to be credited to 
certain districts or 
charged to the muni- 
cipalities comprising 
certain other 
districts 


adminis- 






gencies 






in each 
district 




tration 


Credited 


Charged 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


793.41 


838.42 


723.32 


361.66 


190.42 


4,459.20 


4.212.04 




247.16 


3,857.09 


2,323.56 


1,988.61 


994.30 


527 71 


13,233.20 


12,123.59 




1,109.61 


10,174.62 


5,653.01 


4,738.26 


2,369 13 


1,283 87 


38,806.28 


39,122.90 


316.62 




2,126.71 


915.84 


790.12 


395 06 


208 00 


5,698.39 


3,382.96 




2,315.43 


3,680.20 


1,691.53 


1,459.32 


729.66 


384.17 


12,553.28 


10,433.94 




2,119.34 


2,363.03 


800.42 


690.54 


345.27 


181.78 


7,140.15 


5,359.88 




1,780.27 


4,996.24 


1,912.29 


1,641.02 


820.51 


434.30 


13,337.47 


10,335.89 




3,001.58 


5,081.21 


3,268.51 


2,783.91 

2,724.32 


1 391 96 


742 32 


19,546.47 
28,201.83 


22,491.59 

27,338.72 


2,945.12 




8,504.68 


3,191.76 


1,362.16 


724.89 




863 . 1 1 


1,751.08 


1,405.12 


1,198 63 


599 31 


319 12 


6,862.96 
14,169.82 
13,594.05 

9,862.87 

36,067.55 


6,739.23 




123.73 


3,481.10 


1,807.88 


1 559 70 


779 85 


410 59 


13,596.51 

12,080.99 

8,195 23 




573.31 


3,400.20 


2,372.28 


2,046 62 


1 023 31 


538 77 




1,513.06 


1,885.20 


1,515.33 


1,296.68 

2,785.40 


648 34 


344 15 




1,667.64 


10,043.04 


3,417.79 


1,392.70 


776.21 


36,066.39 




1.16 


6,724.29 


4,107.57 


3 542 49 


1,771.25 
993 90 


932 88 


29,208.20 

21,541.05 

3,781.42 

26,153.23 

37,554.77 
18,725.70 
34,488.48 
50 080 96 


26,339 07 




2,869.13 


7,210.17 


2,366.71 


1 987 80 


537 51 


17,608.63 

2,779.18 

29,043.50 

33,272.88 
18,161 72 




3,932.42 


1,012.55 


762.38 


646 51 


323 26 


173 15 




1,002.24 


5,037.57 


3,143.45 


2,711 .93 

5,730.25 
1 895 51 


1,355.96 

2,865.12 
947 75 


713 91 


2,890.27 




8,931.37 


6,642.05 


1,508.49 
498 99 




4,281.89 


5.349.50 


2,197.13 




563.98 


6,925.20 


3,747.98 


3,130.38 
5,712.85 

2,320.70 


1,565.19 
2,856.43 

1,160.35 


851 21 


32,371.08 
53,557.84 

14,033.27 




2,117.40 


13,592.59 


6,722.21 


1 526 69 


3,476.88 




5,025.14 


2,689.97 


610.92 


16,625.91 




2,592.64 









purposes of rural power districts. 



188 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA SYSTEM— 

Statement showing the costs of distribution of power within each Rural Power 

and the amounts remaining to be credited to certain Districts or charged 

(by annual adjustment) of the actual costs 



District and municipalities 
comprised therein 



Total capital cost of each district, 
Provincial Government grant re- 
ceived and applied thereagainst, 
and the balance representing the 
investment by the Commission 



Total 

capital 

cost 



Govern- 
ment 
grant 



Com- 
mission's 
investment 



Cost of 

power 

delivered 

to districts 

as shown 

in "cost of 

power" 

table 

preceding 



London R.P.D. — Delaware, Lobo, London, 
Nissouri W. and Westminster twps 

Lucan R.P.D.— Biddulph, London, McGil- 
livray and Stephen twps 

Lynden R.P.D. — Ancaster, Beverly, Brant- 
ford and Dumfries S. twps 

Markham R.P.D. — Markham, Pickering, 
Scarborough, Uxbridge and Whitchurch 
twps 

Merlin R.P.D. — Raleigh, Romney and Til- 
bury E. twps 



Milton R.P.D. — Esquesing, Nassagaweya 
Nelson and Trafalgar twps 

Milverton R.P.D. — Ellice, Elma, Morning- 
ton and Wellesley twps 

Mitchell R.P.D.— Downie, Ellice, Elma, 
Fullarton, Hibbert, Logan and McKillop 
twps 

Newmarket R.P.D. — Georgina, Gwillim- 
bury E., King, Scott, Uxbridge and 
Whitchurch twps 

Niagara R.P.D. — Niagara and Stamford 
twps 



Norwich R.P.D. — Burford, Dereham 

Middleton, Norwich N., Norwich S. 

Oxford E. and Windham twps 

Oil Springs R.P.D. — Brooke, Dawn, Ennis 

killen and Euphemia twps 

Palmerston R.P.D. — Arthur, Maryborough 

Minto, Peel and Wallace twps 

Petrolia R.P.D. — Enniskillen, Moore 

Plympton and Sarnia twps 

Preston R.P.D. — Dumfries N., Guelph 

Puslinch, Waterloo and Woolwich twps. 

Ridgetown R.P.D. — Aldborough, Harwich, 
Howard, Orford and Rondeau Park twps. 

St. Jacobs R.P.D.— Peel, Waterloo, Welles 
ley and Woolwich twps 

St. Marys R.P.D. — Blanshard, Downie 
Fullarton, Nissouri E., Nissouri W. and 
Usborne twps 

St. Thomas R.P.D.— Dunwich, Southwold, 
Westminster and Yarmouth twps 

Saltfleet R.P.D.— Barton, Binbrook, Grims- 
by N. and Saltfleet twps 



Sandwich R.P.D. — Anderdon, Colchester 

N., Maidstone, Sandwich E., Sandwich W. 

and Sandwich S. twps 

Sarnia R.P.D. — Moore, Plympton and 

Sarnia twps 

Scarboro R.P.D.— Pickering, Scarboro and 

York N. twps 



$ c. 

♦452,460.60 

♦58,020.83 

103,260.55 

♦228,562.66 
143,247.28 

108,488.53 
65,164.42 

109,781.46 

120,385.47 
♦126,194.33 

♦181,308.61 

29,686.23 

♦60,312.85 

♦26,075.59 

♦318,742.34 

202,560.06 
107,601.88 

192,453.85 
304,957.81 



$ c. 

225,617.74 

28,845.99 

51,210.17 

113,141.14 
71,623.64 

54,244.26 
32,582.21 

54,890.73 

60,192.74 
62,647.51 

88,749.38 
14,843.11 
29,876.28 
12,484.43 
158,093.98 

101,280.03 

53,515.21 

96,226.92 
151,785.16 



294,546.50 143,183.75 



341,428.63 

♦214,251.37 

191,100.81 



170,714.31 

104,924.84 

95,550.41 



$ 


c. 


226,842 


86 


29,174 


84 


52,050 


38 


115,421 


52 


71,623 


64 


54,244 


27 


32,582 


21 


54,890 


73 


60,192 


73 


63,546.82 


92,559 


23 


14,843 


12 


30,436 


.57 


13,591 


.16 


160,648 


.36 


101,280.03 


54,086.67 


96,226.93 


153,172 


.65 



151,362.75 

170,714.32 

109,326.53 

95,550.40 



$ c- 

44,089.51 

1,996.85 

5,871.22 

13,667.35 
7,364.94 

5,833.90 
2,392.38 

5,996.86 

7,898.87 
9,080.52 

8,427.21 

1,772.69 

2,021.78 

972.89 

25,945.67 

10,980.99 

7,887.08 

7,568.26 
14,249.36 

28,553.81 

27,719.20 
18,548.93 
10,007.34 



Items marked * include portions of transmission lines aggregating $44,995.90 used for 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



89 



RURAL POWER DISTRICTS N — RURAL OPERATING 

District, the revenues collected from (or charged to) customers within each District, 

to the Municipalities comprising certain other Districts upon ascertainment 
in the year ending October 31, 1933 



Distribution costs and 


fixed charges 




Total 
cost 


Revenue 

from 

power 

and light 

customers 

in each 

district 


Amounts remaining 


Cost of 
operation 
mainten- 
ance and 
adminis- 


Interest 
(including 
exchange) 


Renewal 
charges 


Obsoles- 
cence 
and 
contin- 
gencies 


Sinking 
fund 


to be credited to 
certain districts or 
charged to the muni- 
cipalities comprising 
certain other 
districts 


tration 


Credited 


Charged 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c.j $ c. 


$ c. 


23,894.84 


10,359.88 


8.913.20 


4,456.60 


2,352.85 


94,066.88 


93,203.47 




863.41 


1,192.16 


1,350.75 


1,158.74 


579.38 


306.77 


6,584.65 


6,542.13 




42.52 


4,536.55 


2,357.16 


2,022.91 


1,011.45 


535.34 


16,334.63 


14,031.73 




2,302.90 


7,552.03 


5,225.01 


4,462.13 


2,231.04 


1,186.66 


34,324.22 


39,491.40 


5,167.18 




3,425.68 


3,267.36 


2,818.83 


1,409.41 


742.06 


19,028.28 


17,837.26 




1,191.02 


4,223.46 


2,469.70 


2,130.67 


1,065.34 


560.90 


16,283.97 


15,225.32 




1,058.65 


2,409.50 


1,482.21 


1,278.74 


639.37 


336.63 


8,538.83 


7,201.22 




1,337.61 


3,748.52 


2,440.38 


2,105.37 


1,052.69 


554.24 


15,898.06 


16,195.71 


297.65 




3,914.38 


2,671.93 


2,305.13 


1,152.57 


606.83 


18,549.71 


19,344.75 


795.04 




9,532.58 


2,912.12 


2,494.37 


1,247.18 


661.39 


25,928.16 


23,248.04 




2,680.12 


8,472.34 


4,249.76 


3,590.22 


1,795.11 


965 . 17 


27,499.81 


25,308.22 




2,191.59 


1,800.59 


685.06 


591.02 


295.51 


155.59 


5,300 46 


5,288.04 




12.42 


1,694.95 


1,401.93 


1,198.27 


599.13 


318.39 


7,234.45 


4,930.36 




2,304.09 


1,163.87 


620.76 
7,166.19 


513.41 
6,131.35 


256.71 
3,065.67 


140.98 
1,627.53 


3,668.62 
55,102.21 


3,599.06 
53,998.49 




69.56 


11,165.80 




1,103.72 


7,479.68 


4,648.66 


4,010.50 


2,005.25 


1,055.77 


30,180.85 


29,529.41 




651.44 


6,101.84 


2,472.39 


2,121.. 55 


1,060.78 


561.51 


20,205.15 


17,133.19 




3,071.96 


5,428.34 


4,408.81 


3,803.58 


1,901.79 


1,001.29 


24,112.07 


20,841.54 




3,270.53 


12,358.85 


6,913.74 


5,936.89 


2,968.44 


1,570.19 


43,997.47 


46,282.43 


2,284.96 




17,636.31 


6,882.96 
7,851.31 


5,774.50 
6,773.50 


2,887.25 
3,386.75 


1,563.20 
1,783.12 


63,298.03 
70,672.66 


65,998.50 
69,667.54 


2,700.47 




23,158.78 


1,005.12 


13,453.68 


4,959.12 


4,190.30 


2,095.16 


1,126.27 


44,373.46 


47,313.52 


2,940.06 




5,993.13 


4,202.75 


3,625.81 


1,812.90 


954.49 


26,596.42 


33,354.35 


6,757.93 





purposes of rural power districts. 



190 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA SYSTEM— 

Statement showing the costs of distribution of power within each Rural Power 

and the amounts remaining to be credited to certain Districts or charged 

(by annual adjustment) of the actual costs 



District and municipalities 
comprised therein 



Total capital cost of each district, 
Provincial Government grant re- 
ceived and applied thereagainst, 
and the balance representing the 
investment by the Commission 



Total 

capital 

cost 



Govern- 
ment 
grant 



Com- 
mission's 
investment 



Cost of 

power 
delivered 
to districts 
as shown 
in "cost of 

power" 

table 

preceding 



Seaforth R.P.D.— Hibbert, Hullett, McKil- 
lop and Tuckersmith twps 

Simcoe R.P.D. — Charlotteville, Townsend, 
Walpole, Windham and Woodhouse twps. 

Stamford R. P. D.— Stamford and Thorold 

twps 

Stratford R.P.D.— Downie, Easthope N., 

Easthope S. and Ellice twps 

Strathroy R.P.D.— Adelaide, Caradoc, Ek- 

frid, Lobo, Metcalfe and Williams E. 

twps 

Streetsville R.P.D. — Chinguacousy, Esque- 

sing, Toronto and Trafalgar twps 

Tavistock R.P.D. — Easthope N., Easthope 

S., Ellice and Zorra E. twps 

Thamesville R.P.D. — Camden, Chatham, 
Euphemia, Harwich, Howard, Orford and 
Zone twps 

Tilbury R.P.D.— Dover W., Mersea, Roch- 
ester, Romney, Tilbury E., Tilbury W. 
and Tilbury N. twps 

Tillsonburg R.P.D. — Bayham, Dereham, 
Dorchester S., Houghton, Malahide, Mid- 
dleton, Norwich N., Norwich S. and Wal- 
singham N. twps 

Wallaceburg R.P.D.— Chatham, Dover E. 
and Sombra twps 

Walsingham R.P.D. — Charlotteville, 
Houghton, Middleton, Walsingham N., 
Walsingham S. and Windham twps 

Walton R.P.D.— Grey, Hullett, McKillop, 
Morris, Wawanosh E. and Wawanosh W. 
twps 

Waterdown R.P.D. — Flamboro E., Flam- 
boro W. and Nelson twps 

Waterford R.P.D. — Townsend and Wind- 
ham twps 

Watford R.P.D.— Adelaide, Metcalfe and 
Warwick twps 

Welland R.P.D.— Bertie, Crowland, Hum- 
berstone, Moulton, Pelham, Thorold, Wain- 
fleet and Willoughby twps 

Woodbridge RP.D. — Albion, Chinguacousy, 
Etobicoke, King, Toronto, Toronto Gore, 
Vaughan and York N. twps 

Woodstock R.P.D.— Blandford, Blenheim, 
Burford, Oxford E., Oxford N., Oxford W.. 
Zorra E. and Zorra W. twps 

Non-operating capital 

Grand totals 

Items marked * include portions of 



$ c. 

29,402.80 

129,831.68 

41,211.74 
67,079.92 

101,204.09 
187,700.07 
120,629.22 

107,547.60 
♦110,648.45 

201,568.67 
154,326.32 

*148,749.14 

*80,210.08 

205,749.58 

117,271.01 

23,904.03 

*652,765.71 

*338,237.05 
224,924.58 



$ c. 
14,083.46 
64,745.55 

20,605.87 
33,279.11 

50,425.27 
93,850.04 
60,314.61 

53,522.31 
54,700.13 

100,784.33 
76,792.14 

73,865.05 

38,349.04 
92,521.64 
58,635.51 
11,952.02 

321,346.74 

168,240.65 
112,462.29 



12,823,206.79 
15,149.60 



6,345,677.89 
7,371.69 



12,838,356 39 6,353,049. 58 6,485,306. 81 810,110 . 29 



$ c. 
15,319.34 
65,086.13 

20,605.87 
33,800.81 

50,778.82 
93,850.03 
60,314.61 

54,025.29 
55,948.32 

100,784.34 
77,534.18 

74,884.09 

41,861.04 

113,227.94 

58,635.50 

11,952.01 

331,418.97 

169,996.40 
112,462.29 



$ c. 
1,942.11 
6,876.76 

4,071.99 
4,598.14 

3,658.40 

10,675.09 

5,087.05 

3,563.14 
6,039.71 

10,433.41 
7,002.40 

6,623.11 

4,132.10 

21,894.57 

4,962.07 

985.51 

30,967.62 

17,636.20 
14,704.05 



6,477,528.90 
7,777.91 



transmission lines aggregating $44,995.90 used for 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



191 



RURAL POWER DISTRICTS N.— RURAL OPERATING 

District, the revenues collected from (or charged to) customers within each District, 

to the Municipalities comprising certain other Districts upon ascertainment 
in the year ending October 31, 1933 



Distribution costs and fixed charges 



Cost of 
operation 
mainten- 
ance and 
adminis- 
tration 



Interest 
(including 
exchange) 



Renewal 
charges 



Obsoles- 
cence 
and 
contin- 
gencies 



Sinking 
fund 



Total 
cost 



Revenue 

from 

power 

and light 

customers 

in each 

district 



1,484.93 
4,835 . 74 

4,659.19 
4,672.33 

2,611.26 
6,690.41 
5,557.04 

3,910.29 
3,159.47 

8,080.12 
6,290.43 

4,136.83 

3,688.75 

13,589.85 

4,002.21 

572.40 

28,211.50 

13,591.40 
10,233.83 



$ c. 

708.06 

2,993.53 

945.43 
1,547.12 

2,328.00 
4,280.02 

2,782.08 



2,494.36 2,141 



$ c. 
586.15 

2,575.77 

815.64 
1,324.30 

2,001.35 
3,692.47 
2,400.16 



2,548.13 

4,633.17 
3,902.45 

3,282.55 



2,173.36 

3,997.14 

3,352.32 

2,811.55 



$ c. 

293.07 

1,287.89 

407.82 
662.16 

1,000.68 
1,846.23 
1,200.08 

1,070.94 
1,086.68 



1,902.07 1,570.71 



5,068.67 

2,672.46 

554.08 

14,680.64 

7,732.95 
5,164.94 



3,958.73 

2,305.59 

478.02 

12,466.75 

6,636.72 
4,455 91 



$ 

160.81 

679.87 

214.72 
351.37 

528.71 
972.04 
631.84 

566.50 
578.71 



1,998.57 1,052.25 
886.29 



1,676.16 
1,405.78 

785.35 
1,979.36 
1,152.80 

239.01 

6,233.38 

3,318.36 
2,227.95 



745.50 

431.98 

1,151.15 

606.95 

125.84 

3,334.13 

1,756.25 
1,173.02 



$ c 

5,175.13 

19,249.56 

11,114.79 
13,155.42 

12,128.40 
28,156.26 
17,658.25 

13,747.11 
15,586.06 

30,194.66 
23,110.05 

19,005.32 

12,510.96 

47,642.33 

15,702.08 

2,954.86 

95,894.02 

50,671.88 
37,959.70 



$ c. 

4,988.00 

18,401.72 

11,625.74 
11,861.74 

11,961.96 
25,199.26 
15,057.50 

13,177.66 
16,141.44 

27,772.02 
21,911.32 

20,529.21 

11,960 01 
49,697.37 

15,682.41 
3,051.33 

92,375.20 

50,554.59 
35,997.86 



Amounts remaining 
to be credited to 
certain districts or 
charged to the muni- 
cipalities comprising 
certain other 
districts 



Credited Charged 



510.95 



$ c. 
187.13 
847.84 



555.38 



1,293.68 

166 44 
2,957.00 
2,600.75 

569.45 



1,523.89 



2,055.04 



96.47 



2,422.64 
1,198.73 



550.95 



19.67 



3,518.82 

117.29 
1,961.84 



557,105.44 294,442.54 251.397.57 125,698.79 66,871.35 



2,105.625 9812,063,370.73 



50.246.15 



92,501.40 



purposes of rural power districts. 



92 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the net Credit or Charge to each Municipality in respect of power 

made and interest added during the year. Also the net amount Credited 

ending October 31, 1933, and the accumulated amount standing 



Municipality 



Date 

commenced 

operating 



Net credit or charge at 
October 31, 1932 



Credit 



Charge 



Cash receipts and 
payments on account 
of such credits and 
charges, also adjust- 
ments made during 
the year 

Credited I Charged 



Acton 

Agincourt. . . . 
Ailsa Craig. . . 
Alvinston .... 
Amherstburg . 

Ancaster twp. 

Arkona 

Aylmer 

Ayr 

Baden 

Beachville. . . . 
Belle River. . . 
Blenheim 

Blyth 

Bolton 

Bothwell 

Brampton. . . . 
Brantford. . . . 
Brantford twp 
Bridgeport . . . 

Brigden 

Brussels 

Burford 

Burgessville. . 
Caledonia. . . . 

Campbellville. 

Cayuga 

Chatham .... 
Chippawa. . . . 
Clifford 

Clinton 

Comber 

Cottam 

Courtright . . . 
Dashwood. . . . 

Delaware .... 
Dorchester. . . 

Drayton 

Dresden 

Drumbo 

Dublin 

Dundas 

Dunnville. . . . 

Dutton 

East Windsor 



Jan., 


1913 


Nov., ] 


1922 


Jan., 


916 


April, 1 


[922 


Nov., 1 


[925 


May, 1 


923 


Dec, 1 


926 


Mar., 1 


918 


Jan., 


915 


May, 1 


[912 


Aug., 1 


[912 


Dec, 1 


[922 


Nov., 1 


L915 


July, 1 


[924 


Feb., ] 


[915 


Sept., 1 


915 


Nov., 1 


911 


Feb., 1 


[914 


May, 1 


924 


Mar., 1 


928 


Jan., 


918 


July, 1 


924 


June, 1 


915 


Nov., 1 


916 


Oct., ] 


[912 


Jan., 1 


[925 


Nov., 1 


924 


Feb., ] 


[915 


Sept., 1 


919 


May, 1 


[924 


Mar., 1 


[914 


May, 


1915 


Nov., 1 


L926 


Dec, 1 


L923 


Sept., 


L917 


Mar., 


1915 


Dec, 


1914 


Mar., 


1918 


April, 


1915 


Dec, 


1914 


Oct., 


1917 


Jan., 


1911 


June, 


L918 


Sept., 


1915 


Nov., 


1922 



289.61 

532.55 



4,595.75 



23.18 

1,499.70 

860.59 

515.07 

1,325.66 
305.29 



642.78 
655.94 



4,145.83 



470.48 

772.85 
833.61 
315.96 



234.05 

144.41 
725.22 
7,288.41 
512.92 
181.36 

577.54 
597.54 
194.97 
99.94 
297.46 

73.87 



652.84 
479.05 



1,497.51 
3,181.73 
1,157.11 
4,731.69 



$ c 
9.50 



24.83 
29.59 



276.51 



627.60 



5,618.58 
286.06 



688.85 



4.43 
65.98 



287.01 



$ c 
9.50 



24.83 
32.26 



276.51 



627.60 



5,618.58 
286.06 



688.85 



0.39 

4.43 

65.98 



289.61 

532.55 



4,595.75 

2.67 

23.18 

1,499.70 

860.59 

515.07 

1,325.66 
305.29 



642.78 
655.94 



4,145.83 



470.48 

772.85 
833.61 
315.96 



234.05 

144.41 

725.22 

7,288.41 

512.92 

181.36 

577.54 
597.54 
194.97 
99.94 
297.46 

74.26 



652.84 
479.05 



1,497.51 
3,181.73 
1,157.11 
4,731.69 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



193 



SYSTEM 



N. —CREDIT OR CHARGE 



supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments 
or Charged to each Municipality in respect of power supplied in the year 
as a Credit or Charge to each Municipality at October 31, 1933 



Interest at 4 % per annum 
added during the year 


Net amount credited or charged 
in respect of power supplied in 
the year endingOctober31, 1933 


Accumulated amount standing 

as a credit or charge on 

October 31, 1933 


Credited 


Charged 


Credited 


Charged 


Credit 


Charge 


$ c. 


$ c. 
0.12 


$ c. 


$ c. 
13.01 


$ c. 


$ c. 
13.13 


4.00 


232.09 


236.09 




9.39 




210.04 


200.65 




0.33 


330.14 
1,754.23 


329.81 
1,826.33 




72.10 








0.44 


357.51 

14.36 

6.17 


357 95 


.38 






13 98 


19.56 






13.39 
60.09 




15.35 




44.74 




7.06 




168.86 


161 80 


18.46 




452.58 


471.04 




5.05 




162.79 


157 74 




4.33 


259.78 
392.91 
529.66 


255.45 
402.98 
539.36 




10.07 






9.70 










9.35 . 


137.89 
1,892.62 
4,467.37 

733.10 
27.04 


147 24 


53.16 






1,839.46 

4,475.92 

737 99 




8.55 
4.89 












6.24 






20 80 


10.25 




355.18 
396.07 
189.59 


365.43 
408 . 95 
194.68 




12.88 








5.09 










11.77 


208 . 45 
659.56 

35.12 
432.41 
523.64 

41.83 
372.01 

495 . 93 


220 22 


3.16 






656 40 


1.98 








33 14 


10.74 








421 67 


100.64 








423 00 


9.82 








32 01 


2.88 








369. 13 


7.78 








488 15 


7.55 




278.70 
70.64 


286.25 
73.70 




3.06 








1.65 




253.32 
89.19 


251 67 


4.09 








85 10 


1.37 


"o.'io" 

0.82 


4.50 


5.87 






234.30 
379.08 


234 40 








379 90 


9.23 


338.43 
258.80 


347.66 
267.07 




8.27 










11.48 


109.99 
1,520.21 


408 48 


24.29 






1,495.92 


44.84 




3,475.50 
340.39 


3,520.34 
354.72 


14.33 








70.00 




1,082.44 


1,012.44 











194 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the net Credit or Charge to each Municipality in respect of power 

made and interest added during the year. Also the net amount Credited 

ending October 31, 1933, and the accumulated amount standing 



Municipality 



Date 

commenced 

operating 



Net credit or charge at 
October 31, 1932 



Credit Charge 



Cash receipts and 
payments on account 

of such credits and 
charges, also adjust- 
ments made during 
the year 



Credited | Charged 



Elmira 

Elora 

Embro 

Erieau 

Erie Beach 

Essex 

Etobicoke 

Exeter 

Fergus 

Fonthill 

Forest 

Gait 

Georgetown 

Glencoe 

Goderich 

Granton 

Guelph 

Hagersville 

Hamilton 

Harriston 

Harrow 

Hensall 

Hespeler 

Highgate 

Humberstone 

Ingersoll 

Jarvis 

Kingsville 

Kitchener 

Lambeth 

La Salle 

Leamington 

Listowel 

London 

London Railway Commission . . 

London twp 

Long Branch 

Lucan 

Lynden 

Markham 

Merlin 

Merritton 

Milton 

Milverton 

Mimico 



Nov., 


1913 


Nov., 


1914 


Jan., 


1915 


July, 


1924 


July, 


1925 


Nov., 


1923 


Aug., 


1917 


June, 


1916 


Nov., 


1914 


June, 


1926 


Mar., 


1917 


May, 


1911 


Sept., 


1913 


Aug., 


1920 


Feb., 


1914 


July, 


1916 


Dec, 


1910 


Sept., 


1913 


Feb., 


1911 


July, 


1916 


Nov., 


1923 


Jan., 


1917 


Feb., 


1911 


Dec, 


1916 


Oct., 


1924 


May, 


1911 


Feb., 


1924 


Nov., 


1923 


Jan., 


1911 


April, 


1915 


Nov., 


1925 


Nov., 


1923 


June, 


1916 


Jan., 


1911 


Aug., 


1914 


Jan., 


1925 


Jan., 


1931 


Feb., 


1915 


Nov., 


1915 


April, 


1920 


Dec, 


1922 


Nov., 


1920 


April, 


1913 


June, 


1916 


May, 


1912 



$ c. 
524.45 
785.20 
842.66 



50.72 

236.36 
6,103.00 
1,357.60 

78.79 



429.11 
14,435.61 



1,677.99 



2,003.92 

539.63 

3,828.92 



471.50 
1,547.18 
1,989.97 

453.45 

311.39 

3,985.55 

899.87 

52,818.01 



,096.56 



191.94 

348.30 

1,063.88 



791.61 
1.043.59 



5.40 



5.40 



129.94 



129.94 



305.46 
540.12 
511.15 

68.59 

4,455.14 



305.46 
545 66 
511.15 

68.59 
4,455.14 



122,122.18 
625.15 



122,122.18 
625 15 



134.68 

534.54 

2,521.53 



134.68 
534.54 

2,521.53 



12.298.53 



12,298.53 



356.08 



356.08 



51.18 
662.61 



51 18 
662.61 



10.98 



10.98 



$ c 
524.45 
785 . 20 
842.66 



50.72 

236.36 

6,103.00 

1,357.60 

78.79 



429.11 
14,435.61 



5.54 



1,677.99 



2,003.92 
539.63 

3,828.92 



471.50 
1,547.18 
1,989.97 

453.45 

311.39 

3,985.55 

899 87 

52,818.01 



1,096.56 



191.94 

348.30 

1,063.88 



791.61 
1,043 '59 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



195 



SYSTEM 



N.— CREDITOR CHARGE 



supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments 
or Charged to each Municipality in respect of power supplied in the year 
as a Credit or Charge to each Municipality at October 31, 1933 



Interest at 4 
added dur 


% per annum 
ing the year 


Net amount credited or charged 
in respect of power supplied in 
the year ending October 31, 1933 


Accumulated amount standing 

as a credit or charge on 

October 31, 1933 


Credited 


Charged 


Credited Charged 


Credit Charge 


$ c. 
7.18 


$ c. 


$ c. 


$ c. 

540.61 

516.81 


$ c. 


$ c. 
533 . 43 


9.98 








506.83 


11.67 




350.58 

263.69 

77.41 


362.25 

263.59 

78.13 






0.10 






0.72 






3.91 




35.06 

" 198 '. 65 " 
886.23 


31.15 


82.27 




2,781.24 


2,863.51 




19.29 




179.36 


1.13 








885 10 




2.32 


321.55 

870.45 
424.70 


319.23 

876.05 
624.46 

"280.*53" 




5.60 






199.76 










4.28 

10.09 

6.89 

1.26 . 
82.02 


807.68 


811.96 




290.62 






1,427.19 

210.56 

2,622.42 

1,989.73 

80,489.92 

607.37 


1,434.08 

211 82 














2,704.44 
1,960 06 


29.67 








2,127.94 
12.07 






82,617.86 
619 44 








30.69 


102.52 


133.21 




10.31 


172.04 


161 73 


61.76 




2,850.17 
134.79 


2,911.93 

132.78 






2.01 
6.95 

43.34 








162.12 

3,712.82 
995.86 


169.07 








3,756.16 
988 06 


7.80 






22.50 




70.34 


92.84 




26.39 




5,493.50 


5,467.11 


8.84 




152.94 
104.24 


161.78 
108.47 


4.23 








62.46 




393.56 

704.11 

7,509.92 

8,333.61 


331 10 


13.81 








690 30 


711.96 








6,797.96 
8,647.14 




313.53 






14.06 


278.35 
618.14 


292.41 
613.34 




4.80 






2.44 


85.69 


S3 25 


7.53 




147.75 
543.53 


155.28 
558. £8 




15.35 










0.72 
8.53 


103.28 
719.66 
1,119.83 
251.62 
195.89 


104 00 








728 19 


9.98 






1,109.85 
251 76 




0.14 






17.27 






178 62 













196 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the net Credit or Charge to each Municipality in respect of power 

made and interest added during the year. Also the net amount Credited 

ending October 31, 1933, and the accumulated amount standing 



Municipality 



Date 

commenced 
operating 



Net credit or charge at 
October 31, 1932 



Credit 



Charge 



Cash receipts and 
payments on account 
of such credits and 
charges, also adjust- 
ments made during 
the year 



Credited | Charged 



Mitchell 

Moorefield 

Mount Brydges. . . . 

Newbury 

New Hamburg 

New Toronto 

Niagara Falls 

Niagara-on-t he-Lake 

Norwich 

Oil Springs 

Otterville 

Palmerston 

Paris 

Parkhill 

Petrolia 

Plattsville 

Point Edward 

Port Colborne 

Port Credit 

Port Dalhousie 

Port Dover 

Port Rowan 

Port Stanley 

Preston 

Princeton 

Queenston 

Richmond Hill 

Ridgetown 

Riverside 

Rockwood 

Rodney 

St. Catharines 

St. Clair Beach 

St. George 

St. Jacobs 

St. Marys 

St. Thomas 

Sandwich 

Sarnia 

Scarboro twp 

Seaforth 

Simcoe 

Springfield 

Stamford twp 

Stouffville 



Sept., 


1911 


Mar., 


918 


Mar., 


L915 


Mar., 


L921 


Mar., 1 


1911 


Feb., 1 


L914 


Dec, 1 


[915 


Aug., 1 


L919 


May, 1 


L912 


Feb., 1 


L918 


Feb., 1 


1916 


July, 1 


[916 


Feb., 1 


[914 


May, 1 


1920 


May, 1 


1916 


Dec, 1 


1914 


Nov., 1 


[916 


Mar., 1 


[920 


Aug., 1 


L912 


Nov., ] 


912 


Dec, 1 


[921 


Nov., 1 


[926 


April, 1 


L912 


Jan., ] 


L911 


Jan., ] 


[915 


Mar., 1 


[921 


June, 1 


[925 


Dec, 1 


L915 


Nov., 1 


[922 


Sept., 


[913 


Feb., 1 


L917 


April, 


L914 


Nov., 


L922 


Sept., 


L915 


Sept., 


[917 


May, 


[911 


April, 1 


[911 


Feb., 


924 


Dec, 


L916 


Aug., 


1918 


Nov., 


1911 


Aug., 


1915 


Aug., 


1917 


Nov., 


916 


Sept., 


1923 



$ c 

1,057.54 

33.40 

550.78 



552.05 
6,749.02 



68.61 
428.82 



2,215.41 

691.96 

1,359.79 

825.29 
2,738.99 



214.50 

274.20 
806 . 94 
.642.85 



1,009.94 

105.39 
1,739.77 



3,201.68 
529.93 



252.82 

29.42 

298.36 

2,632.30 
15,827.24 

5,511.51 
23,767.17 

5,133.02 

285.33 
2,954.96 



983.06 



$ c, 



149.22 



30,619.69 



216.74 



381.81 
275.75 



199.38 
247.95 



222.22 



419.58 



435.48 
12,934.36 



121.83 
609.18 



$ c 



149.22 



336.37 
216.74 



381.81 

275.75 



199.38 
247.95 



222.22 



419.58 



435 . 48 
12,934.36 



121.83 
609.18 



$ c 

1,057.54 

33.40 

550.78 



552.05 
6,749.02 



68.61 
428.82 



2,215.41 

691.96 

1,359.79 

825.29 
2,738.99 



214.50 

274.20 

806.94 

1,642.85 



1,009.94 

105.39 

1,739.77 



3,201.68 
529.93 



252.82 

29.42 

298.36 

2,632.30 
15,827.24 

5,511.51 
23,767.17 

5,133.02 

285.33 
2,954.96 



983.06 



934 



HYDRO-ELECTRIC POWER COMMISSION 



97 



SYSTEM 



N.— CREDIT OR CHARGE 



supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments 
or Charged to each Municipality in respect of power supplied in the year 
as a Credit or Charge to each Municipality at October 31, 1933 



Interest at 4 % per annum 
added during the year 


Net amount credited or charged 
in respect of power supplied in 
the year ending October 31, 1933 


Accumulated amount standing 

as a credit or charge on 

October 31, 1933 


Credited 


Charged 


Credited Charged 


Credit 


Charge 


$ c. 
16.21 


$ c. 


$ c. 


$ c. 

195.84 

171.93 


$ c. 


$ c. 
179.63 


0.49 








1 7 1 . 44 


7.90 




108.39 

50.54 

439.93 

5,841.19 


116.29 

48.58 
447.67 

5,935.12 






1.96 






7.74 






93.93 










1,211.33 


18,404.74 

66.80 

220.71 


49,899.39 


0.93 






65.87 




2.92 






223 . 63 


5.92 


578.83 


584.75 






4.90 
4.38 


168.27 
330.31 
540.79 


173.17 








334 . 69 


31.56 






509.23 


11.25 




87.07 
2,325.04 

258.40 
1,626.75 
1,258.41 


98.32 
2,343.97 

271.58 
1,666.03 
1,255.29 




18.93 








13.18 








39.28 










3.12 
3.48 








827.89 
189.87 


831.37 


2.84 






187.03 


3.85 




1,275.30 

294.00 

1,020.46 


1,279.15 

302.22 

1,057.22 




8.22 








36.76 











2.95 


1,221.18 


1,224.13 


15.83 


520.82 

89.20 

1,719.01 

41.96 


536.65 

90.68 

1,755.00 

35.71 


1.48 








35.99 










6.25 






47.37 


732.20 


684 83 


7.64 




103.47 


111.11 






6.49 

229.86 


388.35 

5,056.45 

109.04 


394 84 








5,286.31 
105 30 


3.74 






0.37 




215.67 . 


216.01 




3.76 






396.03 
2,099.66 


392 27 


42.69 








2,056.97 


230.05 




1,591.19 

973.99 

10,873.22 

4,066.22 


1,821.24 

1,050.70 

11,211.35 

4,134.29 


76.71 








338.13 








68.07 








3.81 




316.44 


312 63 


42.10 




2,195.33 


2,237.43 






1.70 
9.35 


63.79 
1,475.80 


65 49 








1,485.15 


19.80 


248.99 


268.79 











198 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the net Credit or Charge to each Municipality in respect of power 

made and interest added during the year. Also the net amount Credited 

ending October 31, 1933, and the accumulated amount standing 



Municipality 



Date 

commenced 

operating 



Net credit or charge at 
October 31, 1932 



Credit 



Charge 



Cash receipts and 
payments on account 
of such credits and 
charges, also adjust- 
ments made during 
the year 



Credited | Charged 



Stratford 


Jan., 
Dec, 

Aug., 
Nov., 

Nov., 

Feb., 
Oct., 
May, 
Mar., 
Jan., 

April, 
Aug., 
June, 
Aug., 

Nov., 

Feb., 
June, 
Nov., 
April, 
Dec, 

Sept., 

Sept., 

Nov., 

Jan., 

Jan., 

Feb., 
Oct., 
Dec, 
Jan., 
Nov., 

July, 
Nov., 
Sept. 

Jan., 

Feb., 
Sept. 
June, 
Nov. 

Nov. 


1911 
1914 
1923 
1916 
1922 

1914 
1915 
1922 
1914 
1921 

1915 
1911 
1911 
1913 
1914 

1915 
1921 
1911 
1915 
1910 

1917 
1917 
1916 
1917 
1911 

1924 
1914 
1914 
1911 
1916 

1925 
1923 
1917 

1927 

1928 
1930 
1929 
1923 
1922 


$ c 

25,236.86 

3,540.38 

1,281.56 


$ c 


$ c 


$ c 
25,236.86 


Strathroy 






3,540.38 


Sutton 






1,281.56 


Tavistock 


512.16 


512.16 




Tecumseh 


1,285.29 
451.58 


1,285.29 


Thamesford 






451.58 


Thamesville 


188.03 


188.03 




Thedford 


54.12 
164.69 
705.82 

1,833.67 
1,151.98 
69,566.26 
1,723.27 
9,900.02 

750.53 


54.12 


Thorndale 




5.56 


170.25 


Thorold 




705.82 


Tilbury 






1,833.67 


Tillsonburg . . 






1,151.98 


Toronto 






69,566.26 


Toronto twp... 






1,723.27 


Walkerville 






9,900.02 


Wallaceburg 






750.53 


Wardsville . . 


147.77 


147.77 
326.83 




Waterdown 


674.64 

650.51 

3,855.37 

644.19 


1,001.47 


Waterford 




650.51 


Waterloo 






3,855.37 


Watford 






644.19 


Wei land 


4,105.12 
218.78 


4,140.87 
218.78 


35.75 


Wellesley . . 






West Lome. . 


49.56 
3,705.30 

695.94 

39,254.28 

292.01 

5,128.64 


49.56 


Weston . . . 






3,705.30 


Wheat ley 






695.94 








39,254.28 


Woodbridge 






292.01 


Woodstock 






5,128.64 


Wyoming 


352.34 


352.34 




York East twp. 


3,310.59 


3,310.59 


York North twp. 


761.30 


761.30 




Zurich 


542.00 

1,820.35 


542.00 


Toronto Transportation Comm . 

Rural Power District* 
Acton R.P.D. 






1,820.35 


416.70 




30.00 


Ailsa Craig R.P.D 

Alvinston R P D 


42.22 






413.45 






Amherstburg R.P.D 

Aylmer R.P.D 


27,651.27 
13,222.77 




148.56 






883.51 









*For townships included in rural power districts see "Cost of Power" and "Rural Operating' 
statements preceding. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



199 



SYSTEM 



N.— CREDIT OR CHARGE 



supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments 
or Charged to each Municipality in respect of power supplied in the year 
as a Credit or Charge to each Municipality at October 31, 1933 



Interest at 4 % per annum 
added during the year 


Net amount credited or charged 
in respect of power supplied in 
the year ending October 31, 1933 


Accumulated amount standing 

as a credit or charge on 

October 31, 1933 


Credited 


Charged 


Credited Charged 


Credit Charge 


% c. 
376.71 


$ c. 


$ c. 

2,756.37 

2,132.17 

504.99 

665.99 


$ c. 


$ c. 

3,133.08 

2,187.65 

524.95 

658.13 


$ c. 


55.48 








19 96 










7.86 






19.01 


128.49 
76.01 


109.48 


6.28 








69 . 73 




3.71 


357.95 

497.13 

57.04 

38.36 


354.24 

498.03 

59.66 

47.87 




0.90 






2.62 








9.51 








27.61 




164.20 


136.59 


15.15 




30.73 


45.88 




937.71 




118,851.10 


117,913.39 


24.17 




1,472.78 


1,496.95 


146.47 




4,981.98 
711.90 


4,835.51 
701 54 


10.36 










3.77 


43.17 
126.04 
486.71 


39.40 
137.64 
494.84 




11.60 




8.13 








48.17 




14,197.04 


14,148.87 


10.66 




1,037.11 


1,047.77 




112.06 
2.90 


572.39 


684.45 




49.34 

50.81 

1,642.37 


46.44 

51.54 

1,698.00 




0.73 






55.63 








10.16 




219.96 
8,015.38 


209 80 


546.33 








7,469.05 


3.90 




475.00 


478.90 


82.62 




4,667.50 


4,584.88 




5.33 


269.47 

2,353.09 
1,244.66 


264.14 

2,396.63 
1,229.81 


43.54 








14.85 






7.66 


127.04 


119 38 


29.99 




359.71 


389.70 






16.67 


251.34 

74.49 

196.43 


714 71 


1.69 






30.58 




16.54 






626 42 


1,105.82 


3,157.82 
1,594.09 


31,766.35 
14,460.63 




527.28 

















200 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the net Credit or Charge to each Municipality in respect of power 

made and interest added during the year. Also the net amount Credited 

ending October 31, 1933, and the accumulated amount standing 



Rural power 


district* 


Date 

commenced 

operating 


Net credit or charge at 
October 31, 1932 


Cash receipts and 
payments on account 
of such credits and 
charges, also adjust- 
ments made during 
the vear 




Credit Charge 


Credited ( Charged 



Ayr R.P.D 

Baden R.P.D 

Beamsville R.P.D.. 
Belle River R.P.D. 
Blenheim R.P.D.. 

Bond Lake R.P.D.. 
Bothwell R.P.D.. . 
Brampton R.P.D.. 

Brant R.P.D 

Brigden R.P.D.. . . 

Burford R.P.D. ... 
Caledonia R.P.D.. 
Chatham R.P.D.. . 
Chippawa R.P.D.. 
Clinton R.P.D. . . 

Delaware R.P.D. . 
Dorchester R.P.D. 

Dresden R.P.D 

Drumbo R.P.D 

Dundas R.P.D 

Dunnville R.P.D.. 

Dutton R.P.D 

Elmira R.P.D 

Elora R.P.D 

Essex R.P.D 

Exeter R.P.D 

Forest R.P.D 

Gait R.P.D 

Georgetown R.P.D 
Goderich R.P.D. . 

Grantham R.P.D. 

Guelph R.P.D 

Haldimand R.P.D. 
Harriston R.P.D.. . 
Harrow R.P.D 

Ingersoll R.P.D.. . . 

Jordan R.P.D 

Keswick R.P.D 

Kingsville R.P.D.. . 
Listowel R.P.D 

London R.P.D 

Lucan R.P.D 



July, 


1926 


Sept., 


1922 


Jan., 


1923 


Dec, 


1922 


July, 


1924 


Mar., 


1924 


Dec, 


1923 


Nov., 


1923 


Oct., 


1922 


Jan., 


1927 


Dec, 


1926 


Oct., 


1925 


May, 


1922 


July, 


1922 


July, 


1928 


Oct., 


1922 


Dec, 


1921 


May, 


1928 


Aug., 


1922 


Jan., 


1922 


July, 


1928 


Feb., 


1926 


June, 


1926 


Jan., 


1926 


Nov., 


1924 


Nov., 


1922 


Nov., 


1926 


Oct., 


1922 


Nov., 


1924 


June, 


1925 


Nov., 


1924 


Jan., 


1925 


Oct., 


1925 


Dec, 


1929 


Nov., 


1923 


Oct. 


1922 


May, 


1922 


Mar., 


1924 


Nov., 


1923 


Oct., 


1926 


Nov., 


1922 


June, 


1926 



$ c 

929.50 



42,906.65 
31,123.02 
15,790.10 

48,163.85 

6,868.19 

919.69 



2,612.52 



17,757.86 
3,331.26 



3.602.59 



1,190.94 
19,959.94 



17,870.19 
12,726.42 



2,729.5 
2,485.24 



1,083.72 
' 4,132.77 
16,262.32 



12,619.14 



34,612.32 
587.85 

17,784.51 



$ c. $ c 



2,618.01 



3,050.86 
3,264.22 



2,611.19 



1.921.11 



1,861.59 
305.41 



2,725.54 
693.35 

1,580.47 
629.88 



235.14 



1,942.70 



7,324.28 
1,241. Oi 



2,192.54 
6,781 .22 



298.13 



88.15 



187 


HI 


814 


15 


177 


07 


30 


00 


932 


99 


172 


94 


117 


69 


1,590 


00 


20 


00 


300 


00 


1,287 


82 


60 


71 


150 


00 


240 


00 


656 


52 


417 


98 



429.27 



596.55 

30.00 

122.00 

204.08 

20.00 



3.50 

372.59 

40.00 

674.21 
174.36 
726.86 
20.00 
120.00 

113.50 
174.01 
334.97 
320.00 
144.76 
V 
174.10 



*For townships included in rural power districts see '"Cost of Power" and "Rural Operating' 
statements preced-ng. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



201 



SYSTEM 



N.— CREDIT OR CHARGE 



supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments 
or Charged to each Municipality in respect of power supplied in the year 
as a Credit or Charge to each Municipality at October 31, 1933 



Interest at 4 % per annum 
added during the year 


Net amount credited or charged 
in respect of power supplied in 
the year ending October 31, 1933 


Accumulated amount standing 

as a credit or charge on 

October 31, 1933 


Credited 


Charged 


Credited 


Charged 


Credit 


Charge 


$ c. 
37 18 


$ c. 


$ c. 


$ c. 
1,275.26 
3,320.11 


$ c. 


$ c. 
308.58 




104.72 






6,230 65 


1,715.08 

1,244.54 

631.60 


1,110.55 
1,585.93 
2,395.57 

4,665.38 


44,918.13 
33,776.42 
18,787.27 

53,817.20 
6,459.85 
















1,920.96 
274 73 




' 






510.13 
1,461.14 

5,214.29 
1,192.55 

379.20 
2,685.01 

148.48 

25.89 

1,271.81 

251.28 




36 38 






622.76 




122.03 
130.57 






9,977.18 








4,607.34 


104 50 




2,037.82 






111.72 




6,695.74 


709.92 




18,258.59 
3,288.62 




133.25 










76.84 




3,509.76 


139 65 




2,834.44 






76.61 

12.22 


422.90 


1,933.28 




247.16 
1,109.61 




564.79 


47.64 




128.97 
20,644.73 




797.44 




316.62 






109.02 
37.01 
63.22 
25.39 


2,315.43 
2,119.34 
1,780.27 
3,001.58 


5,149.99 








3,446.25 








3,453.96 








3,778.85 


714 69 


2,945.12 


21,325.92 

12,352.37 




509.06 




863.11 

123.73 

573.31 

1,513.06 

1,667.64 

1.16 
2,869.13 
3,932.42 
1,002.24 






9.41 




368.28 


109.18 




2,261.88 
698.86 




99.27 










77.71 




3,728.05 


42.91 




451.26 






292.97 




10,659.74 


165.31 






361.20 




49.64 






2,312.89 


650 . 49 


2,890 27 


19,683.08 






87.93 


4,281.89 

563.98 

2,117.40 


6,676 86 


504 14 




12,385.29 






273.72 




9,507.31 


1,384.79 

23.43 


3,476.88 


39,242.14 






2,592.64 

863.41 

42.52 


2,126.12 


710.43 






17,457.43 






11.93 




352.58 











202 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA 

Statement showing the net Credit or Charge to each Municipality in respect of power 

made and interest added during the year. Also the net amount Credited 

ending October 31, 1933, and the accumulated amount standing 



Rural power district* 


Date 

commenced 

operating 


Net credit or charge at 
October 31, 1932 


Cash receipts and 
payments on account 
of such credits and 
charges, also adjust- 
ments made during 
the year 




Credit | 


Charge 


Credited | Charged 


Lvnden R.P.D 


Feb., 
Dec, 
Nov., 

Jan., 

Aug., 

Dec, 

Mar., 

Jan., 

May, 
Dec, 
Oct., 
Aug., 
April, 

Mar., 
Nov., 
Dec, 
Aug., 
Feb., 

July, 
June, 
Dec, 
Nov., 
Nov., 

Mar., 
July, 
Dec, 
Nov., 
April, 

Nov., 
Dec, 
Dec, 
Jan., 
Dec, 

Nov., 
Oct., 

Nov., 
Dec, 
April 

Jan., 
Feb., 


1922 
1922 
1928 

1925 
1927 
1925 
1924 
1922 

1925 
1925 
1926 
1923 
1922 

1922 
1922 
1927 
1923 
1922 

1922 
1923 
1923 
1927 
1922 

1922 
1924 
1926 
1922 
1923 

1927 
1923 
1923 
1923 
1926 

1924 
1922 
1923 
1929 
1922 

1923 
1922 


$ c 

93.69 

26,582.07 


$ c 


$ c 


$ c 
190.36 


Markham R.P.D 






412.60 


Merlin R.P.D.. . 


3,649.49 




431.56 


Milton R.P.D 


5,783.96 




112.85 


Milverton R.P.D 


4,126.27 






Mitchell R.P.D 


1,681.50 

5,826.65 

22,007.03 

7,626.78 
2,772.93 




60.00 


Newmarket R.P.D 






11.32 


Niagara R.P.D 

Norwich R.P.D 




5.00 


270.00 




64.16 


Oil Springs R.P.D 

Palmerston R.P.D 








3,715.48 
534.60 




40.00 


Petrolia R.P.D.. 








Preston R.P.D 


9,160.16 

2,183.20 
3,743.01 




780.02 


Ridgetown R.P.D 

St. Jacobs R.P.D 






71.70 






272.70 


St. Marys R.P.D 

St. Thomas R.P.D 


7,765.93 




80.00 


17,561.83 
1,945.81 

61,622.41 
13,072.95 
24,294.55 




310.00 


Saltfleet R.P.D 






1,753.10 


Sandwich R.P.D 






5,959.80 


Sarnia R.P.D 






150.39 


Scarboro R.P.D. . . 






2,140.02 


Seaforth R.P.D. . . 


358.05 




90.00 


Simcoe R.P.D. 


3,311.29 

8,061.14 
207.31 




291.86 


Stamford R.P.D 






2,368.71 


Stratford R.P.D 








Strathroy R.P.D 

Streetsville R.P.D 


508.48 




40.00 


19,271.56 




7,404.43 


Tavistock R.P.D.. 


5,967.91 




182.38 


Thamesville R.P.D 


1,212.47 
5.007.08 
6,953.77 
9,511.49 
3,055.17 

2,473.41 
41,936.16 

"43,190.23 

15,615.02 
11,761.89 




183.60 


Tilbury R.P.D 






90.00 


Tillsonburg R.P.D 

Wallaceburg R.P.D 

Walsingham R.P.D 

Walton R.P.D 






172.84 






160.00 






90.00 






40.00 


Waterdown R.P.D 






1,818.84 


Waterford R.P.D 


738.78 
346.86 




170.00 


Watford R.P.D. 






Welland R.P.D... 




9,859.53 


Woodbridge R.P D 






282.33 


Woodstock R.P.D. 






87.57 










Totals 




1,139,553.57 


276,189.54 


176,270.45 


452,892.61 









*For townships included in rural power districts see "Cost of Power" and "Rural Operating" 
statements preceding. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



203 



SYSTEM 



N.— CREDIT OR CHARGE 



supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments 
or Charged to each Municipality in respect of power supplied in the year 
as a Credit or Charge to each Municipality at October 31, 1933 



Interest at 4 % per annum 
added during the year 



Credited 



Charged 



Net amount credited or charged 
in respect of power supplied in 
theyearendingOctober31, 1933 



Credited 



Charged 



Accumulated amount standing 

as a credit or charge on 

October 31, 1933 



Credit 



Charge 



$ c. 
3.68 


$ c. 


$ c. 


$ c. 
2,302.90 


$ c. 


$ c. 
2,395.89 


1,061.58 




5,167.18 


32,398.23 






145.98 


1,191.02 

1,058.65 
1,337.61 


5,418.05 


229.60 




4,842.06 






165.05 




5,628.93 


67.26 


297.65 
795.04 


1,986.41 

6,843.32 

19,942.28 

5,675.39 
2,871.43 




232.95 








880.37 




2,680.12 

2,191.59 
12.42 

2,304.09 
69.56 

1,103.72 

651.44 
3,071.96 
3,270.53 




304.36 








110.92 










148.62 
21.38 




6,208.19 








625.54 


364.32 




7,640.74 

1,547.39 
547.61 




87.33 








149.26 










310.64 . 




11,427.10 


702.47 


2,284.96 
2,700.47 


20,239.26 
2,967.79 

57,122.09 
16,385.27 
29,875.94 




74.61 








2,464.60 




1,005.12 




522.65 




2,940.06 
6,757.93 




963.48 










14.32 


187.13 
847.84 


649.50 


132.15 




2,303.74 
6,503.41 




300.03 




510.95 




8.29 




1,293.68 

166.44 

2,957.00 

2,600.75 

569.45 


1,078 08 




20.34 






735.26 


769.42 




9,679.55 






240.24 




8,991 28 


48.50 




507.92 
5,672.74 
4,633.66 
8,533.22 
4,611.27 

1,981.40 
43,849.81 




200 . 28 




555.38 




275.37 




2,422.64 
1,198.73 




380.46 








122.21 




1,523.89 




98.94 




550.95 




1,677.45 




2,055.04 






29.55 
13.87 


19.67 


958 00 




96.47 




264.26 


1,604.45 


3,518.82 

117.29 
1,961.84 


31,416.33 

15,838.30 
10,181.57 




622.90 








469.09 
















35,000.91 


7,134.20 


124,787.46 


413,104.46 


810,579.69 


484,288.11 



204 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 



NIAGARA SYSTEM 
Reserve for Renewals — October 31, 1933 

Total provision for renewals to October 31, 1932 $18,065,909.62 

Deduct: 

Expenditures to October 31, 1932 1,436,017 .09 

Balance brought forward October 31, 1932 $16,629,892.53 

Added during the year ending October 31, 1933: 

Amounts charged to municipalities and rural power districts 

as part of the cost of power delivered to them $1,064,624.94 

Amounts included in costs of distribution of power within 

rural power districts 251,397.57 

Provision against equipment employed in respect of contracts 

with private companies which purchased power and 

against equipment in local distribution systems 312,153 .93 

Payments by Ottawa Valley Power Company in respect of 

Chats Falls transformer station under agreement 12,141 .91 

Reserve provided in respect of lines transferred to certain 

rural power districts from power properties 2,070.37 

Reserve provided in respect of equipment transferred 1,406.49 

Interest at 4 % per annum on the monthly balances at the 

credit of the account 665,334.77 

2,309,129.98 



$18,939,022.51 
Deduct: 

Expenditures during the year ending October 31, 1933 252,832 . 62 



Balance carried forward October 31, 1933 $18,686,189.89 



1934 HYDRO-ELECTRIC POWER COMMISSION 205 



NIAGARA SYSTEM 
Reserve for Obsolescence and Contingencies — October 31, 1933 

Balance brought forward October 31, 1932 $12,440,735 .02 

Added during the year ending October 31, 1933: 

Amounts included in the costs of distribution of power within 

rural power districts $125,698 . 79 

Adjustment in respect of power delivered to private com- 
panies in the year ending October 31, 1932 1,118.84 

Payments by Ottawa Valley Power Co. in respect of Chats 

Falls transformer station under agreement 13,133 .32 

Share of profits realized in respect of the sale of certain of 

the Commission's investment securities 44,203 . 20 

Profit on English exchange in connection with 
transfer of funds to London to retire 
debenture stock $820,516.50 

Less — Commission's share of American ex- 
change paid during the year by the 
Province of Ontario and by the Commis- 
sion on the transfer of funds to New York 
to meet capital retirements 118,008.83 



Interest at 4% per annum on monthly balances 

at the credit of the account 497,629.40 



702,507.67 

1,384,291.22 



Deduct: 

Interest on Commission's advances to, and 
investment in the capital stock of, the 

Hamilton Street Railway Company $164,220.43 

in excess of profit for the year (before pro- 
vision for renewal of road and equipment) 
from operation of the street railway 27,307.72 



$13,825,026.24 



$136,912.71 



Contingencies met with during the year incidental to plant 

operations 272,571 . 70 

Cost to the Commission (including provisions for sinking 
fund $431,003.02 and renewals $312,153.93) of power 
delivered to private companies and customers under 
flat rate contracts in excess of the revenue received from 
them 2,221,034.43 

Amount appropriated to provide a reserve for the Com- 
mission's claim against Dominion Government in respect 
of income tax 72,334 . 46 

Amount appropriated from the contingency reserve and 
applied proportionately to each municipality in reduc- 
tion of the cost of delivery of power thereto 2,015,572 .30 

4,718,425.60 

Balance carried forward October 31. 1933 $9,106,600.64 



206 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA SYSTEM 



SINKING FUND 



Statement showing Sinking Fund paid by each Municipality in the periods mentioned 

hereunder as part of the cost of power delivered thereto, together with 

its proportionate share of other sinking funds provided out 

of other revenues of the system and interest allowed 

thereon to October 31, 1933 



Municipality 



Acton 

Agincourt 
Ailsa Craig. . . 

Alvinston 

Amherstburg. . 

Ancaster twp . 

Arkona 

Aylmer 

Ayr 

Baden 

Beachville. . . . 
Belle River . . . 

Blenheim 

Blyth 

Bolton 

Bothwell 

Brampton 
Brantford . . . . 
Brantford twp 
Bridgeport. . . . 

Brigden 

Brussels 

Burford 

Burgessville. . . 
Caledonia . . . . 

Campbellville . 

Cayuga 

Chatham 

Chippawa . . . . 
Clifford 

Clinton 

Comber 

Cottam 

Courtright. . . . 
Dash wood. . . . 

Delaware 

Dorchester. . . 

Drayton 

Dresden 

Drumbo 

Dublin 

Dundas 

Dunnville. . . . 

Dutton 

East Windsor. 



Period of 
years ending 
Oct. 31, 1933 



16 years 

9 " 

13 " 
10 " 
16 " 

10 " 

7 " 

10 " 

14 " 
16 " 

16 ■ 

11 u 
13 " 
10 " 
13 " 

13 u 

17 " 

14 " 

10 " 

6 " 

11 « 

10 « 
13 " 

12 " 

16 ■ 

9 " 

9 " 

13 " 

11 u 
10 u 

14 " 
13 " 

7 " 

10 " 

11 " 

13 « 

14 " 

10 u 

13 " 

14 « 

11 • 

17 " 

10 " 
13 u 

11 " 



Amount 



$ 
34,576 
5,182 
9,541 
9,622 



27,567.04 

8,321.47 
2,948.25 

22,779.10 
8,153.15 

19,259.17 

23,913.36 
5,164.20 

21,191.34 
4,935.50 

10,636.75 

11,113.15 

93,084.35 

473,680.24 

15,720.56 

2,607.10 

7,049.89 
6,968.52 
7,656.25 
3,190.64 
12,346.64 

860.46 

4,608.67 

222,270.09 

9,683.44 

3,400.81 

26,385.91 

11,265.98 

1,912.56 

3,068.73 

4,929.81 

1,607.07 
3,991.12 
6,777.75 
17,862.77 
3,658.36 

3,357.12 

81,992.63 

32,056.77 

11,117.92 

125,360.56 



Municipality 



Elmira 

Elora 

Embro 

Erieau 

Erie Beach 

Essex 

Etobicoke twp 

Exeter 

Fergus 

Fonthill 

Forest 

Gait 

Georgetown 

Glencoe 

Goderich 

Granton 

Guelph 

Hagersville 

Hamilton 

Harriston 

Harrow 

Hensall 

Hespeler 

Highgate 

Humberstone 

Ingersoll 

Jarvis 

Kingsville 

Kitchener 

Lambeth 

LaSalle 

Leamington 

Listowel 

London 

London Ry. Comn 

London twp 

Long Branch 

Lucan 

Lynden 

Markham 

Merlin 

Merritton 

Milton 

Milverton 

Mimico 



Period of 
years ending 
Oct. 31, 1933 



15 years 
14 
14 
10 
9 

10 
11 
12 
14 



11 
17 
15 
10 
14 

12 
17 
15 
17 
12 

10 
12 
17 
12 
10 

17 
10 
10 
17 
13 

8 
10 
12 
17 
14 

9 

3 

13 

13 

10 

10 
12 
15 
12 
16 



Amount 



$ c. 

46,936.38 

22,693.58 

6,527.33 

2,938.52 

747.87 

15,657.28 
92,232.23 
23,307.91 
28,771.67 
2,800.14 

16,729.43 
313,276.52 
55,732.50 
10,750.22 
70,410.65 

4,760.53 

368,952.35 

47,251.46 

2,173,195.35 

19,021.07 

11,158.25 
8,596.60 

56,882.64 
5,893.16 
9,735.62 

105,017.04 

7,844.51 

21,171.01 

704,233.55 
5,287.52 

6,920.00 

38,294.17 

40,935.07 

1,276,199.72 

84,384.56 

7,958.96 
6,340.04 
11,298.71 
8,470.87 
9,223.04 

7,210.65 
51,801.81 
62,216.95 
27,538.79 
74,423.84 



934 



HYDRO-ELECTRIC POWER COMMISSION 



207 



NIAGARA SYSTEM 



SINKING FUND 



Statement showing Sinking Fund paid by each Municipality in the periods mentioned 

hereunder as part of the cost of power delivered thereto, together with 

its proportionate share of other sinking funds provided out 

of other revenues of the system and interest allowed 

thereon to October 31, 1933 



Municipality 



Mitchell 

Moorefield 

Mount Brydges. 

Newbury 

New Hamburg. . 

New Toronto . . . 
Niagara Falls . . . 
Niagara-on-Lake 

Norwich 

Oil Springs 

Otterville 

Palmerston 

Paris 

Parkhill 

Petrolia 

Plattsville 

Point Edward. . . 
Port Colborne. . . 
Port Credit. 
Port Dalhousie. . 

Port Dover 

Port Rowan .... 
Port Stanley. . . . 

Preston 

Princeton 

Queenston 

Richmond Hill. . 

Ridgetown 

Riverside 

Rockwood 

Rodney 

St. Catharines. . 
St. Clair Beach. . 

St. George 

St. Jacobs 

St. Marys 

St. Thomas 

Sandwich 

Sarnia 

Scarboro twp . . . 

Seaforth 

Simcoe 

Springfield 

Stamford twp. . . 
Stouffville 



Period of 
years ending 
Oct. 31, 1933 



17 years 

10 " 

13 " 
10 " 

17 " 

14 " 

13 " 

10 ■ 

16 u 

10 " 

12 " 

12 " 

14 " 

10 " 

12 « 

14 " 

11 " 

12 " 
16 " 

12 " 

10 " 

7 " 

16 " 

17 " 

14 " 

10 " 
9 " 

13 " 

11 " 

15 " 

11 " 

12 u 
11 * 

13 « 

11 " 

17. " 

17 u 

10 " 

12 " 

10 " 

17 " 

13 « 

11 u 

12 " 
10 ■ 



Amount 



$ c 

25,154.35 

3,564.98 

3,954.00 

2,459.74 

28,962.42 

233,643.69 

322,289.01 

16,284.04 

21,467.24 

14,703.00 

4,586.52 
24,034.50 
65,116.46 
10,093.35 
58,101.13 

5,100.27 
25,866.17 
49,150.47 
19,681.98 
16,815.86 

12,733.61 
3,408.20 

22,072.23 

155,142.27 

4,534.68 

3,708.42 

8,304.53 

23,153.15 

43,095.44 

6,373.61 

6,962.59 
290,602.66 
3,600.11 
7,663.23 
7,966.38 

76,957.11 
264,228.94 
125,752.20 
328,029.30 

84,438.89 

37,447.48 
49,310.53 

5,308.21 
48,099.73 

7,758.09 



Municipality 



Stratford . 
Strathroy. 
Sutton . . . 
Tavistock . 
Tecumseh 



Thamesford. 
Thamesville 
Thedford. . . 
Thorndale. . 
Thorold .... 



Tilbury 

Tillsonburg. . 

Toronto 

Toronto twp. 
Walkerville . . 



Wallaceburg 
Wardsville. . 
Waterdown. 
Waterford. . 
Waterloo. . . 



Watford 

Welland... 
Wellesley. . . 
West Lome. 
Weston 



Wheatley. . . 
Windsor. . . . 
Woodbridge 
Woodstock . 
Wyoming. . . 



York East twp. . 
York North twp. 
Zurich 



Toronto Trans. Com. 
Sandwich, Windsor & 
Amherstburg Ry. Co. 
Windsor, Essex & 
Lake Shore Railway 
Association 



Period of 
years ending 
Oct. 31. 1933 



17 years 
14 " 

10 " 
12 " 

11 " 



14 
13 
10 

14 
11 



10 
14 
14 
17 
12 



9 
10 
11 



12 " 
11 « 

4 " 



Amount 



$ c. 

341,228.19 

47,541.31 

7,140.47 

24,238 67 

13,344.22 



9,606.22 
9,545.28 
4,809.74 
5,154.87 
45,966.73 



24,728.27 

47,955.04 

10,262,345.03 

48,982.20 

356,447.26 



102,741.31 

1,876.72 

13,365.35 

17,475.90 

142,961.10 



11,763.78 

148,814.76 

9,904.27 

16,699.36 
125,872.53 



6,384.47 

1,056,217.61 

16,082.48 

210,352.26 

4.467.98 



116,767.89 

49,580.68 

7,563.75 



130,530.48 
101,335.75 

9,259.79 



208 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA SYSTEM 



SINKING FUND 



Statement showing Sinking Fund paid by each Municipality in the periods mentioned 

hereunder as part of the cost of power delivered thereto, together with 

its proportionate share of other sinking funds provided out 

of other revenues of the system and interest allowed 

thereon to October 31, 1933 





Period 






Period 






of years 






of years 




Rural power district* 


ending 

Oct. 31, 

1933 


Amount 


Rural power district* 


ending 

Oct. 31, 

1933 


Amount 






$ c. 






$ c. 


Acton R.P.D 


6 years 


405 75 


London R.P.D 


1 1 years 


54,493.27 


Ailsa Craig R.P.D 


4 " 


170.17 


Lucan R.P.D 


8 " 


3,332.92 


Alvinston R.P.D 


5 " 


202.32 


Lynden R.P.D 


12 " 


8,580.31 


Amherstburg R.P.D 


10 " 


25,798.26 


Markham R.P.D 


11 " 


14,665.29 


Aylmer R.P.D 


12 " 


12,872.68 


Merlin R.P.D 


5 " 


6,114.96 


Ayr R.P.D 


8 " 


1,621.95 


Milton R.P.D 


9 " 


5,397.17 


Baden R.P.D 


12 " 


12,436.62 


Milverton R.P.D 


7 " 


2,540.21 


Beamsville R.P.D 


11 " 


37,770.12 


Mitchell R.P.D 


8 " 


7,252.84 


Belle River R.P.D 


11 " 


12,380.64 


Newmarket R.P.D 


10 " 


9,169.68 


Blenheim R.P.D 


10 " 


6,342.27 


Niagara R.P.D 


12 " 


19,264.59 


Bond Lake R.P.D 


10 " 


28,437.76 


Norwich R.P.D 


9 " 


16,848.79 


Bothwell R.P.D 


10 " 


5,657.07 


Oil Springs R.P.D 


8 " 


2,490.86 


Brampton R.P.D 


10 " 


4,711.20 


Palmerston R.P.D 


7 " 


1,480.01 


Brant R.P.D 


12 " 


16,315.54 


Petrolia R.P.D 


11 " 


1,314.67 


Brigden R.P.D 


7 " 


2,729.97 


Preston R.P.D 


12 " 


33,516.33 


Burford R.P.D 


7 " 


4,853.22 


Ridgetown R.P.D 


12 " 


16,433.13 


Caledonia R.P.D 


9 " 


9,601.41 


St. Jacobs R.P.D 


11 " 


10,503.65 


Chatham R.P.D 


12 " 


18,909.14 


St. Marys R.P.D 


6 " 


8,598.99 


Chippawa R.P.D 


12 " 


6,281.65 


St. Thomas R.P.D 


11 " 


23,105.95 


Clinton R.P.D 


6 " 


5,051.52 


Saltfleet R.P.D 


12 " 


39,176.80 


Delaware R.P.D 


11 " 


14,701.73 


Sandwich R.P.D 


12 " 


46,136.33 


Dorchester R.P.D 


12 « 


20,064.21 


Sarnia R.P.D 


11 " 


22,963.59 


Dresden R.P.D 


6 " 


1,145.60 


Scarboro R.P.D 


10 " 


10,388.35 


Drumbo R.P.D 


12 " 


6,047.40 


Seaforth R.P.D 


6 " 


1,883.47 


Dundas R.P.D 


12 " 


19,963.40 


Simcoe R.P.D 


11 " 


7,194.26 


Dunnville R.P.D 


6 " 


917.32 


Stamford R.P.D 


12 " 


6,005.06 


Dutton R.P.D 


8 " 


3,795.94 


Stratford R.P.D 


10 " 


8,514.34 


Elmira R.P.D 


8 " 


1,864.68 


Strathroy R.P.D 


7 " 


3,587.60 


Elora R.P.D 


8 " 


4,986.77 


Streetsville R.P.D 


11 " 


13,199.60 


Essex R.P.D 


9 " 


10,071.77 


Tavistock R.P.D 


11 " 


7,224.75 


Exeter R.P.D 


11 " 


12,796.31 


Thamesville R.P.D 


6 " 


4,152.17 


Forest R.P.D 


7 " 


1,634.31 


Tilbury R.P.D 


10 " 


5,252.35 


Gait R.P.D 


12 " 


6,112.59 


Tillsonburg R.P.D 


10 " 


19,917.27 


Georgetown R.P.D 


9 " 


4,842.98 


Wallaceburg R.P.D 


11 " 


12,098.06 


Goderich R.P.D 


9 " 


3,747.23 


Walsingham R.P.D 


7 " 


5,969.83 


Grantham R.P.D 


9 " 


20,922.32 


Walton R.P.D 


9 " 


4,262.46 


Guelph R.P.D 


9 " 


10,164.29 


Waterdown R.P.D 


11 " 


18,372.66 


Haldimand R.P.D 


9 " 


5,674.11 


Waterford R.P.D 


10 " 


5,891.90 


Harriston R.P.D 


4 " 


714 81 


Watford R.P.D 


4 " 


743.09 


Harrow R.P.D 


10 " 


12,227.93 


Welland R.P.D 


12 " 


53,087.00 


Ingersoll R.P.D 


12 " 


13,565.80 


Woodbridge R.P.D 


11 " 


28,184.12 


Jordan R.P.D 


12 " 


8,170.83 


Woodstock R.P.D 


12 " 


24,376.66 


Keswick R.P.D 


10 " 


14,553.94 


Total 


$24,. 


564,512.19 


Kingsville R.P.D 


10 " 


32,901.03 








Listowel R.P.D 


7 " 


4.849.35 









*For townships included in rural power districts see "Cost of Power" and "Rural Operating" 
statements preceding. 



934 HYDRO-ELECTRIC POWER COMMISSION 209 



NIAGARA SYSTEM 
Reserve for Sinking Fund — October 31, 1933 

Total provision for sinking fund to October 31, 1932. $21,808,954.04 

Provided in the year ending October 31, 1933, in respect of: 

Advances by the Province for construction of transmission 

lines and stations $488,381 .90 

Advances by the Province for construction of rural power 

districts 66,871 .35 

Advances by the Province for construction of pipe line to 

Ontario Power generating station 36,923 .85 

Advances by the Province for construction of Queenston- 

Chippawa development 809,295 21 

Bonds issued and assumed by the Commission in connection 
with the purchase of the properties of the Ontario Power 
Company, Toronto Power Companv, Essex system and 
Thorold system 481,727 .68 

Interest at 4 % per annum on amounts standing at the credit 

of the reserve accounts 872,358 . 16 

2,755,558.15 

Total $24,564,512 . 19 



210 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NIAGARA SYSTEM— RURAL LINES 

Statement showing Interest, Sinking Fund, Renewals and Contingencies charged by 

the Commission to the Municipalities which operate the respective 

rural lines for the year ending October 31, 1933 



Operated by 


Capital 
cost 


Interest 


Sinking 
fund 


Renewals 


Contin- 
gencies 


Total interest, 

sinking fund, 

renewals and 

contingencies 

charged 


Milton 


$ c. 
15,909 84 
19,617.60 


$ c. 
789.13 
823.94 


$ c. 
286.38 
353.12 


$ c. 
318.20 
392.35 


$ c. 
159.10 
196.18 


$ c. 
1,552 81 


Welland 


1,765 59 






Totals 


35,527.44 


1,613.07 


639.50 


710.55 


355.28 


3,318.40 



NIAGARA SYSTEM— RURAL LINES 
Reserve for Renewals — October 31, 1933 

Total provision for renewals to October 31, 1932 $5,570 . 79 

Deduct: 

Expenditures to October 31, 1932 288.03 

Balance brought forward October 31, 1932 $5,282.76 

Added during the year ending October 31, 1933: 

By charges against the municipalities which operate the lines ' $710.55 

Interest at 4 % per annum on monthly balances at the credit of the 

account ^ 211.31 

921.86 

Balance carried forward October 3 1 , 1933 $6,204 . 62 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



211 



NIAGARA SYSTEM— RURAL LINES 
Reserve for Contingencies — October 31, 1933 

Balance brought forward October 31, 1932 $2,588.80 

Added during the year ending October 31, 1933: 

By charges against municipalities which operate the lines $355 .28 

Interest at 4 % per annum on monthly balances at the credit of the 

account 103 55 

— 458.83 

Balance carried forward October 31, 1933 $3,047 .63 



NIAGARA SYSTEM— RURAL LINES 

Statement showing the total Sinking Fund paid in respect of each line, together with 
interest allowed thereon to October 31, 1933 





Lines operated by 


Period of years 

ending 
October 31, 1933 


Amount 


Milton 


20 years 

21 u 


$ c. 
3,432.62 


Welland. '. - 


10,613.50 








Total . . . 


14,046.12 









NIAGARA SYSTEM— RURAL LINES 
Reserve for Sinking Fund— October 31, 1933 

Total provision for sinking fund to October 31, 1932 

Provided in the year ending October 31, 1933 

Interest at 4 % per annum on the amount standing at the credit of the account 



$12,890.98 
639.50 
515.64 

$14,046.12 



212 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



GEORGIAN BAY 
Operating Account for Year 

Costs of operation as provided under the terms of the Power Commission Act 

Power purchased $27,316.52 

Costs of operation and maintenance, including the proportion of 
administrative expenses chargeable to the operation of the system : 

General and transmission equipment $381,803 .94 

Rural power districts 56,844 . 72 

Water heater costs written off in year to extent of revenue avail- 
able from water heater loads 1 ,360 . 10 

440,008.76 

Interest (including exchange thereon) on capital investment in: 

Generation and transmission equipment $360,090.48 

Rural power districts 36,600 . 19 

396,690.67 

Provision for renewal of: 

Generation and transmission equipment $99,221 .22 

Rural power districts 28,890 . 44 

128,111.66 

Provision for obsolescence and contingencies in respect of: 

Generation and transmission equipment $28,258.29 

Rural power districts 28,890 . 44 

57,148.73 

Provision for sinking fund: 

By charges included in the cost of power delivered to munici- 
palities and rural power districts $73,332 .45 

By charges against contracts with private companies which 

purchased power 6,507 .93 

By charges included in the cost of distribution of power within 

rural power districts 7,986.56 

87,826.94 

$1,137,103.28 



GEORGIAN BAY 

Statement showing the amount to be paid by each Municipality as the Cost — under 

received by the Commission from each Municipality on account of such cost; 

upon ascertainment (by annual adjustment) of the actual cost 



Municipality 



Interim rates 

per 
horsepower 
collected by 
Commission 
during year 



To 

Jan. 1 

1933 



To 

Oct. 31 

1933 



Share of 

capital cost 

of system 

on which 

interest and 

fixed 

charges are 

payable 



Average 
horse- 
power 

supplied 
in year 

after cor- 
rection 

for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange 



Alliston 

Arthur 

Barrie 

Beaver^on 

Water heater load 
Beeton 



Bradford 

Brechin 

Cannington 

Water heater load 
Chatsworth . . 
Chesley 



Water heater load 



$ c. 


$ c. 


$ c. 


60.00 


60.00 


93,245.06 


75.00 


75.00 


69,439.48 


36.00 


36.00 


586,604.30 


43.00 


43.00 


54,558.64 


75.00 


75.00 


59,115.84 


70.00 


70.00 


64,418.93 


58.00 


55.00 


19,602.61 


45.00 


45.00 


47,543.65 


45.00 


45.00 


16,338.44 


40.00 


40.00 


137,164.84 



212 


9 


128 


8 


,251 


6 


179 


4 


1 





104 


7 


134 





51 


9 


153 


6 





3 


52 


3 


472 


2 


1 


6 



$ c. 
246.61 
149.19 
2,608.13 
207.81 



121.28 

155.22 

60.12 

177.92 



60.58 
546.97 



$ c. 
4,160.11 
3,848.78 
9,559.87 
3,407.74 

*43.39 


$ c 

4,425.63 

3,275.27 

27,838.16 

2,550.39 


2,443.99 

3,170.93 

1,091.10 

2,864.87 

*13.06 


2,794.71 

3,045.69 

914.44 

2,232.49 


1,185.01 

6,620.21 

*60.07 


778.42 
6,498.72 



*Heater costs written off in year to extent of revenue available from heater loads. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



213 



SYSTEM 

Ending October 31, 1933 

Revenue for period 

Collected from municipalities $863,748 . 55 

Power sold to private companies 62,987 . 29 

Collected from customers in rural power districts 236,399.48 



-$1,163,135.32 



Add 



Amounts due by certain municipalities, being the difference 
between the sums paid and the cost of power supplied to 
them in the year 

Amounts due by municipalities comprising certain rural power 
districts, being the difference between the revenue collected 
from customers therein and the cost of power supplied to 
them in the year 



$5,337.24 



33,035.17 



38,372.41 



$1,201,507.73 



Deduct: 

Amounts collected from certain municipalities in excess of the 
sums required to be paid by them for power supplied in the 
year $61,309.81 

Amounts collected from customers in certain rural power districts 

in excess of the cost of power delivered thereto 3,094 .64 

64,404.45 

Revenue $1,137,103. 28 

$1,137,103.28 



SYSTEM G.B.— COST OF POWER 

the Power Commission Act — of Power supplied to it by the Commission; the amount 
and the amount remaining to be credited or charged to each Municipality 
of power supplied to it in the year ending October 31, 1933 



costs and fixed charges 




Cost in 
excess of 

revenue 
from power 

sold to 

private 
companies 


Total cost 

of power 

for year as 

provided to 

be paid 

under 

Power 

Commission 

Act 


Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 




Renewals 


Obsoles- 
cence and 
contin- 
gencies 


Sinking 
fund 


Amounts remaining to 
be credited or charged 
to each municipality 
upon ascertainment of 
the actual cost of power 
by annual adjustment 

Credited 1 Charged 


$ c. 
1,404.09 


$ c. 

310.39 

227.94 

2,208.93 

202.72 


$ c. 

981.00 

729.57 

6,173.52 

573.82 


$ c. 

164.23 

99.35 

1,736.85 

138.39 


$ c. 

11,692.06 

9,438.03 

76,995.12 

7,783.85\ 

43.39] 

7,207.65 

8,367.51 

2,663.73 

6,686. 98\ 

13.06] 

2,518.59 

17,728.301 

60.07( 


$ c. 

13,238.12 

10,034.11 

84,121.28 

8,034.60 

8,135.12 

9,703.83 
2,986.37 
7,166.80 

2,438.41 
19,658.84 


$ c. 
1,546.06 

596.08 
7,126.16 

207.36 

927.47 

1,336.32 
322.64 
466 . 76 


$ c. 


1,107.93 

6,869.66 

702.98 








955.33 
998.54 


189.71 

215.88 

71.81 

174.99 


621.87 

677.88 
206.31 
499.94 


80.76 

103.37 

40.03 

118.48 




279.92 
618.29 




215.75 


65.52 
530.41 


172.97 
1,443.82 


40.34 
364.25 


80.18 


1,723.92 


1,870.47 









214 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



GEORGIAN BAY 

Statement showing the amount to be paid by each Municipality as the Cost — under 

received by the Commission from each Municipality on account of such cost; 

upon ascertainment (by annual adjustment) of the actual cost 



Municipality 



Interim rates 

per 
horsepower 
collected by 
Commission 
during year 



To 

Jan. 1 

1933 



To 

Oct. 31 

1933 



Share of 

capital cost 

of system 

on which 

interest and 

fixed 

charges are 

payable 



Average 
horse- 
power 

supplied 
in year 

after cor- 
rection 

for power 
factor 



Share of operating 



Cost of 


Operating, 


power 


main- 


pur- 


tenance 


chased 


and 




adminis- 




trative 




expenses 



Interest 
(including 
exchange) 



Cold water 

Water heater load 
Collingwood 

Water heater load 

Cookstown 

Creemore 

Dundalk 

Durham 

Water heater load 

Elmvale 

Elmwood 

Flesherton 

Grand Valley 

Gravenhurst 

Hanover 

Water heater load 

Holstein 

Huntsville 

Water heater load 
Kincardine 

Water heater load 

Kirkfield 

Lucknow 

Markdale 

Water heater load 
Meaford 

Water heater load 
Midland 

Water heater load 

Mildmay 

Mount Forest 

Neustadt 

Orangeville 

Water heater load 
Owen Sound 

Water heater load 

Paisley 

Penetanguishene 

Water heater load 
Port Elgin 

Water heater load 

Port McNicoll 

Port Perry 



$ c. 
39.00 



40.00 



60.00 
55.00 
42.00 

42.00 



43.00 
53.00 
45.00 
58.00 

24.00 
35.00 



90.00 
26.00 



58.00 



60.00 
63.00 
40.00 



46.00 
35.00 



60.00 
48.00 
70.00 
45.00 



36.00 



55.00 
40.00 



40.00 



38.00 
50.00 



$ c. 
39.00 



40.00 



60.00 
55.00 
42.00 

45.00 



43.00 
50.00 
50.00 
60.00 

28.00 
35.00 



90.00 
28.00 



58.00 



60.00 
63.00 
40.00 



46.00 
35.00 



60.00 
50.00 
70.00 
48.00 



36.00 



60.00 
40.00 



40.00 



42.00 
52.00 



$ c. 
46,757.06 



372,399.07 



20,317.93 
41,559.11 
44,739.14 

110,220.03 



44,000.51 
18,321.43 
24,978.44 
42,848.34 

123,251.04 

244,743.65 



14,491.22 
225,369.17 



198,043.04 



11,025.25 
86,045.36 
41,943.59 



136,569.77 
653,715.41 



19,886.90 
114,732.39 

30,586.21 
198,253.24 



827,269.38 



52,780.42 
169,665.45 



63,647.31 



24,518.37 
74,755.98 



149.3 


0.3 


1,227.0 


1.8 


50.9 


103.3 


156.3 


369.6 


0.6 


152.6 


59.9 


75.6 


103.8 


609.4 


918.2 


1.6 


17.2 


951.5 


1.2 


474.1 


2.8 


22.6 


182.2 


150.3 


0.4 


387.4 


0.6 


2,513.3 


3.8 


57.9 


329.4 


30.7 


539.6 


2.3 


3,151.0 


3.1 


111.0 


556.9 


1.8 


210.8 


1.3 


83.7 


187.6 



$ c. 
172.94 



1,421.29 



58.96 
119.66 
181.05 

428.12 



176.76 
69.38 
87.57 

120.24 



1,063.59 



19.92 

549'. 17 



26.18 
211.05 
174.10 



448 . 74 
2,911.27 



67.07 
381.56 

35.56 
625.04 



3,649.96 



128.58 
645.08 



244.18 



96.95 
217.30 



$ c. 
2,621.17 

*12.88 
20,534.53 

*73.99 
1,040.24 
2,554.45 
2,606.43 

6,795.19 
*25.48 
2,711.95 
1,098.39 
1,561.06 
2,423.38 

6,055.20 

11,464.66 

*54. 38 

826.58 

12,925.53 

♦37.81 

8,935.70 

♦147.26 

553.33 

3,902.32 

2,337.35 

♦15.16 

6,342.98 

♦26.98 

31,788.27 

♦127.44 

1,088.12 

6,282.25 

972.24 

9,854.82 

♦109.80 

40,295.34 

♦105.40 

2,283.51 
7,523.41 

♦68.34 
3,247.57 

♦52.07 
1,278.15 
3,801.96 



$ c. 
2,209.99 



17,438.98 



962.97 
1,966.06 
2,117.81 

5,203.33 



2,064.67 

871.21 

1,182.15 

2,020.10 

5,865.82 
11,511.28 



685.97 
10,671.10 



9,410.26 



520.27 
4,095.09 
1,992.31 



6,512.16 
30,729^93 



959.37 
5,430.91 
1,440.45 
9,344.07 



39,251 


54 


2,514 
7,950 


43 

37 


3,062 


19 



1,161.90 
3,550.40 



♦Heater costs written off in year to extent of revenue available from heater loads. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



215 



SYSTEM 



G.B.—COST OF POWER 



the Power Commission Act — of Power supplied to it by the Commission; the amount 
and the amount remaining to be credited or charged to each Municipality 
of power supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Obsoles- 
cence and 
contin- 
gencies 



Sinking 
fund 



Cost in 
excess of 

revenue 
from power 

sold to 

private 
companies 



Total cost 

of power 

for year as 

provided to 

be paid 

under 

Power 

Commission 

Act 



Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 



Amounts remaining to 
be credited or charged 
to each municipality 
upon ascertainment of 
the actual cost of power 
by annual adjustment 



Credited Charged 



$ c. 
612.84 



4,798.54 



296.26 
609 . 67 
557.26 

1,406.41 



550.56 
237.11 
304.17 
630 . 63 

1,146.46 
2,912.37 



252.69 
2.450.02 



2,923.82 



171.48 

1,327.57 

480.98 



1,895.16 
7,648*53 



257.31 
1,583.15 

545.43 
2,763.11 



9,732.57 



815.99 
2,190.68 



817.92 



309.67 
1,086.56 



$ c. 
183.45 



1,376.63 



75.29 
148.20 
170.60 

417.51 



170.33 
74.13 
91.05 

149.48 

486.22 
968.62 



42.45 
830.21 



671.68 



36.65 
291.96 
155.63 



484.18 
2,388 '. 93 



77.47 
402.33 

88.39 
689.82 



3,070.49 



180.66 
618.94 



239.15 



96.33 
249.99 



$ c. 
492.18 



3,919.65 



213.78 
438.28 
470.88 

1,160.15 



463.14 
192.85 
262.94 
449.89 

1,295.58 
2,575.96 



152.57 
2,370.34 



2,077.72 



115.95 
905.85 
441.52 



1,437.69 
6,880.74 



209.34 
1,207.55 

322.03 
2,067.48 



8,702.08 



555.66 
1,785.74 



670.00 



258.08 
785.09 



$ c. 
115.17 



946.49 



39.26 

79.68 

120.57 

285.10 



117.71 
46.21 
58.32 
80.07 

470.08 
708.28 



13.27 
733.98 



365.71 



17.43 
140.55 
115.94 



298.83 
1,938.72 



44.66 
254.09 

23.68 
416.24 



2,430.63 



85.62 
429.58 



162.61 



64.56 

144.71 



$ c. 
6,407.741 

12.881 
50,436.111 

73. 99 J 
2,686.76 
5,916.00 
6,224.60 



15,695 
25 
6,255 
2,589 
3,547 
5,873 



15,319.36 

31,204.761 

54.38/ 

1,993.45 

29,981. 18\ 

37.81/ 

24,934.061 

147.26/ 

1,441.29 
10,874.39 
5,697.83 
15.16 
17,419.74 
26.98/ 
84,286.39/ 
127.44/ 

2,703.34 

15,541.84 

3,427.78 

25,760.581 

109.80/ 

107,132. 61\ 

105.40/ 

6,564.45 
21,143.801 

68.34/ 
8,443. 62 \ 

52.07/ 
3,265.64 
9.836.01 



$ 

6,049 


c. 
49 


51,019 


69 


3,152 
5,887 
6,796 


66 
63 

35 


17,075 


87 


6,788.35 
3,126.02 
3,836.84 
6,423.96 


16,663 
33,483 


25 
03 


1,615 
27,211 


08 
74 


28,718 


31 


1,411.26 

11,918.03 

6,246.07 


18,532 


68 


91,445 


55 


3,618 
16,936 

2,232 
26,699 


66 

35 
28 
88 


117,805 


83 


6,834 
23,214 


75 
94 


8,813 


18 


3,569 

10,055 


92 

25 



c. 



509.59 
465.90 



571.75 

1,354.58 

533.23 
536.74 
289.58 
550.17 

1,343.89 
2,223.89 



3,636.99 



1,043.64 
533.08 

1,085.96 

7,031.72 



915.32 
1,394.51 



829.50 
10.567.82 



270.30 
2,002.80 

317.49 

304.28 
219.24 



$ c. 
371.13 



28.37 



378.37 
2.807.25 



30.03 



195.50 



216 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



GEORGIAN BAY 

Statement showing the amount to be paid by each Municipality as the Cost — under 

received by the Commission from each Municipality on account of such cost; 

upon ascertainment (by annual adjustment) of the actual cost 



Municipality 



Interim rates 

per 
horsepower 
collected by 
Commission 
during year 



To 

Jan. 1 

1933 



To 

Oct. 31 

1933 



Share of 

capital cost 

of system 

on which 

interest and 

fixed 

charges are 

payable 



Average 
horse- 
power 

supplied 
in year 

after cor 
rection 

for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



Priceville 

Ripley 

Rosseau 

Shelburne 

Water heater load 
Southampton 

Water heater load 

Stayner 

Water heater load 

Sunderland 

Tara 

Teeswater 

Thornton 

Tottenham 

Uxbridge 

Victoria Harbour 

Walkerton 

Water heater load 
Waubaushene 

Water heater load 

Wiarton 

Windermere 

Wingham 

Woodville 



$ c. 
85.00 
80.00 
127.00 
46.00 



40.00 



44.00 



60.00 
53.00 
58.00 
85.00 

92.00 
55.00 
46.00 
38.00 



44.00 



65.00 

100.00 

60.00 

56.00 



$ c. 
85.00 
80.00 
127.00 
46.00 



40.00 



44.00 



63.00 
53.00 
60.00 
80.00 

95.00 
55.00 
46.00 
38.00 



44.00 



65.00 
85.00 
60.00 
58.00 



Rural Power District 

Alliston R.P.D. — Essa, Tecumseth and 
Tossorontio twps 

Arthur R. P. D— Luther E. and Luther 
W. twps 

Bala R.P.D.— Wood and Medora twp 
Water heater load 

Barrie R.P.D. — Innisfil, Oro and Ves- 

pra twps 

Water heater load 

Baysville R.P.D.— Franklin, Macau- 
lay, McLean, Ridout and Sherbourne 
twps 

Beaumaris R.P.D. — Macaulay 
Monck, Muskoka and Wood and 

Medora twps 

Water heater load 



$ c. 

8,628.88 

33,261.70 

29,386.39 

67,053.06 



59,238.29 



59,023.33 



25,625.78 
26,298.75 
47,019.77 
10,778.54 

42,835.45 

84,314.89 

23,206.10 

121,227.75 



13,822.58 



110,415.76 
16,347.24 

129,101.62 
24,573.30 



29,659.00 

1,320.95 
28,730.33 



77,475.19 



7,444.69 



35,465.73 



16.7 

55.7 

33.1 

197.9 

0.2 

210.4 

1.9 

193.9 

0.8 

57.4 

73.2 

106.4 

20.5 

60.1 
201.5 

72.5 
443.0 

3.5 
50.1 

0.4 

207.8 
32.6 

261.1 
58.0 



78.6 

3.2 

103.6 

0.8 

235.0 




47.9 



143.2 
2.0 



$ c. 
19.34 
64.52 



229.24 
243.71 



224.60 



66.49 

84.79 

123.25 

23.75 

69.62 
233.41 

83.98 
513.15 



58.03 



240 . 70 



302.44 
67.18 



91.05 

3.71 
120.01 



272.21 



$ c. 

412.91 
1,561.29 
1,259.54 
4,140.49 
♦9.64 
3,425.19 

♦74.63 

3,594.03 
*34.53 
1,458.23 
1,262.12 
2,365.42 
572.45 

1,639.76 
4,157.92 
1,222.36 
6,181.93 
♦126.08 
1,067.31 
♦17.46 

5,383.18 

868.99 

5,587.98 

1,330.18 



1,276.04 

67.19 

1,365.73 

♦28.48 

3,555.02 
♦4.29 



1,169.02 



1,730.12 
♦62.22 



$ c. 

408.11 
1,580.81 
1,413.48 
3,154.90 



2,848.75 



2,792.33 



1,195.12 

1,238.86 

2,228.01 

508.50 

2,029.58 
4,009.68 
1,096.42 
5,830.58 



653.75 



5,314.70 

784.65 

6,113.49 

1,143.93 



1,420.32 

62.94 
1,376.21 



3.702.40 



839.99 



1,692.19 



♦Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



217 



SYSTEM 



G.B.—COST OF POWER 



the Power Commission Act — -of Power supplied to it by the Commission; the amount 
and the amount remaining to be credited or charged to each Municipality 
of power supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Obsoles- 
cence and 
contin- 
gencies 



Sinking 
fund 



Cost in 
excess of 

revenue 
from power 

sold to 

private 
companies 



Total cost 

of power 

for year as 

provided to 

be paid 

under 

Power 

Commission 

Act 



Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 



Amounts remaining to 
be credited or charged 
to each municipality 
upon ascertainment of 
the actual cost of power 
by annual adjustment 



Credited | Charged 



$ c. 
135.24 
545.01 
515.76 
907.09 



730.61 



761.83 



388.23 
367.94 
710.70 
171.23 

726.06 
1,248.08 

307.63 
1,350.21 



168.31 



1.759.69 
256.42 

2,018.38 
365.88 



423.21 

19.44 
325.49 



1,041.68 



245.35 



400.28 



$ c. 

37.67 
106.65 

89.97 
249.32 



229.93 



225.13 



86.39 
100.28 
180.36 

39.05 

133.13 

283.71 

87.76 

464.65 



55.59 



361.25 
57.58 

443.21 
82.64 



103.39 

4.61 
109.62 



308.81 



77.14 



148.30 



$ c. 

90.16 
350.19 
309.13 
702.29 



623.57 



621.27 



269.58 
276.84 
495.00 
113.43 

450.51 

885.91 

244.29 

1,276.03 



145.50 



1,162.43 
172.02 

1,359.15 
258.49 



312.07 

13.87 
302.33 



815.29 



183.57 



373.35 



$ c. 
12.88 
42.97 
25.53 

152.66 



162.30 



149.57 



44.28 
56.47 
82.08 
15.81 

46.36 
155.43 

55.93 
341.72 



38.65 



160.29 

25.15 

201.41 

44.74 



60.63 

2.47 
79.92 



181.27 



36.95 



110.46 



$ c. 
1,116.31 
4,251.44 
3,613.41 
9,535.99) 
9.64/ 
8,264.06 

74.63 

8,368.76 
34.53 
3,508.32 
3,387.30 
6,184.82 
1,444.22 

5,095.02 

10,974.14 

3,098.37 

15,958.271 

126.081 

2,187.141 

17.46J 

14,382.24 
2,164.81 

16,026.06 
3.293.04 



3,686.71 

174.23 

3,679.31 

28.48 

9,876.68 
4.29 



2,552.02 



4,454.70 
62.22 



$ c. 
1,466.36 
4,625 49 
4,361.26 
9,438.60 

8,798.42 



8,867.50 

3,712.00 
3,993.16 
6,589.41 
1,712.72 

5,885.69 
11,500.94 

3,453.27 
17,602.68 

2,296.04 



14/042.86 
2,915.47 

16,326.01 
3.460.29 



3,686.71 

174.23 
3.707.79 



9,880.97 



2,552.02 



4,516.92 



$ c: 
350.05 
374.05 
747.85 



459.73 



464.21 

203.68 
605.86 
404.59 
268.50 

790.67 

526.80 

354.90 

1,518.33 

91.44 



750.66 
299.95 
167.25 



see page 



107.03 



339.38 



223 



218 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



GEORGIAN BAY 

Statement showing the amount to be paid by each Municipality as the Cost — under 

received by the Commission from each Municipality on account of such cost; 

upon ascertainment (by annual adjustment) of the actual cost 



Rural power district 



Share of 

capital cost 

of system 

on which 

interest and 

fixed 

charges are 

payable 



Average 
horse- 
power 

supplied 
in year 

after cor- 
rection 

for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expen es 



Interest 
(including 
exchange) 



Beaverton R.P.D. — Brock, Georgina, 
Mara and Thorah twps 

Beeton R.P.D. — Tecumseth twp... 

Bradford R.P.D.— Gwillimbury W. 
King and Tecumseth twps 

Bruce R.P.D.— Brant, Carrick, Cul 
ross, Greenock and Saugeen twps. 
Water heater load 

Buckskin R.P.D. — Matchedash and 

Wood and Medora twps 

Cannington R.P.D.— Brock, Eldon 

and Mariposa twps 

Chatsworth R.P.D.— Holland twp... 
Cookstown R.P.D. — Essa and Innisfil 

twps 

Creemore R.P.D.- 

prey, Sunnidale 

twps , 



Nottawasaga, Os- 
and Tossorontio 



Elmvale R.P.D.— Flos, Medonte, Oro 
and Vespra twps 

Flesherton R.P.D. — Artemesia twp.. 

Gravenhurst R.P.D. — Muskoka twp. 

Hawkestone R.P.D. — Orillia and Oro 
twps 

Holstein R.P.D. — Bentinck, Egremont 
and Normanby twps 



Huntsville R.P.D.— Brunei, Chaffey 
and Franklin twps 

Innisfil R.P.D. — Gwillimbury W. and 

Innisfil twps 

Water heater load 

Lucknow R.P.D. — Kinloss twp 

Mariposa R.P.D. — Brock, Mariposa 
and Reach twps 

Markdale R.P.D. — Artemesia, Eu- 
phrasia, Glenelg and Holland twps.. 



St. Vincent twp.. . 
-Baxter and Tay 



Meaford R.P.D.- 
Medonte R.P.D 

twps 

Water heater load 
Midland R.P.D. — Tay and Tiny twps. 

Neustadt R.P.D. — Bentinck twp 

Nottawasaga R.P.D. — Nottawasaga 

twp 



41,769.58 
2,145.55 

20,439.71 

38,289.76 



5,604.47 

11,810.71 
3,909.54 

319.32 



18,556.34 



19,643.14 
2,556.06 
5,080.26 

613.46 



10,803.44 
69,476.44 



43,455.20 
10,694.49 



5,683.53 
5,856*59 



8,339.94 



129.0 
3 

40.9 

99.9 
0.1 



13.8 

36.0 

8.7 

0.8 



55.0 



60.0 

8.0 

23.0 

67.7 



36.4 

178.4 
0.3 



128.6 
29.6 



20.6 

0.2 

22.9 



25.9 



149.42 
4.40 

47.38 

115.71 



15.98 

41.70 

10.08 

0.93 



63.71 



69.50 
9.27 



1,567.34 



206.65 



148.96 
34.29 



23.86 



26.53 
30.00 



2,517.95 
80.49 

860.38 

1,653.29 
*3.82 



223.42 

621.57 
300.96 

13.80 



953.45 



889.77 
127.31 
351.46 

126.44 



640.04 

2,889.20 
♦14.37 



2,099.81 
550.47 



335.78 

*7.77 

342.09 



473.32 



2,000.80 
103.15 

982.12 

1,842.02 



267.50 

552.19 
187.18 

15.30 



891.21 



937.90 
120.42 
241.70 

25.66 



518.15 
3,325.29 



2,053.35 
512.84 



272.50 
280.38 



387.28 



*Heater costs written off in vear to extent of revenue available from heater loads. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



219 



SYSTEM 



G.B.—COST OF POWER 



the Power Commission Act — of Power supplied to it by the Commission; the amount 
and the amount remaining to be credited or charged to each Municipality 
of power supplied to it in the year ending October 31, 1933 



costs and fixed charges 


Cost in 
excess of 

revenue 
from power 

sold to 

private 
companies 


Total cost 

of power 

for year as 

provided to 

be paid 

under 

Power 

Commission 

Act 


Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 






Renewals 


Obsoles- 
cence and 
contin- 
gencies 


Sinking 
fund 


Amounts remaining to 
be credited or charged 
to each municipality 
upon ascertainment of 
the actual cost of power 
by annual adjustment 














Credited | Charged 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


556.28 
34.67 


155.22 
6.89 


439.36 

22.57 


99.50 
2.93 


5,918.53 
255.10 


5,918.53 
255.10 


see page 


223 

a 


320.32 


69.78 


215.09 


31.55 


2,526.62 


2,526.62 


It 


u 


542.19 


140.32 


403.09 


77.08 


4,773. 70\ 
3.82/ 

683 . 14 


4,777.52 


a 


u 


82.30 


24.29 


59.00 


10.65 


683 . 14 


u 


a 


158.26 
59.41 


42.84 
16.90 


124.20 
41.16 


27.77 
6.71 


1,568.53 
622.40 


1,568.53 
622.40 


u 
u 


a 
it 


4.66 


1.18 


3.36 


0.62 


39.85 


39.85 


" 


* 


252.37 


68.39 


195.32 


42.43 


2,466.88 


2,466.88 


» 


u 


263.32 

30.44 
51.84 


80.34 
10.18 
20.52 


206.77 
26.91 
53.41 


46.28 

6.17 

17.74 


2,493.88 
330 . 70 
736.67 


2,493.88 
330.70 
736.67 


u 
a 
a 


a 

a 
it 


12.28 


3.06 


6.46 


52.22 


1,793.46 


1,793.46 


a 

u 


u 


137.36 


42.67 


113.65 


28.08 


1,479.95 


1,479.95 


u 


It 


1,003.67 


249.67 


731.00 


137.61 


8,543.091 

14.37/ 


8,557.46 


It 
u 


It 










a 


590.25 


156.71 


456.79 


99.20 


5,605.07 


5,605.07 


a 


147.85 


44.98 


112.58 


22.84 


1,425.85 


1,425.85 


u 

see page 

It 

It 
it 

u 


it 

225 


69.20 


22.86 


59.82 


15.89 


799.91) 

7.77/ 
817.42 


807.68 
817.42 




67.70 


21.41 


61.65 


17.66 


a 

it 


110.88 


31.45 


87.78 


19.98 


1,140.69 


1,140.69 


it 



220 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



GEORGIAN BAY 

Statement showing the amount to be paid by each Municipality as the Cost — under 

received by the Commission from each Municipality on account of such cost; 

upon ascertainment (by annual adjustment) of the actual cost 











Share of operating 




Share of 
capital cost 


Average 
horse- 














Rural power district 


of system 

on which 

interest and 

fixed 


power 
supplied 

in year 
after cor- 


Cost of 
power 
pur- 
chased 


Operating, 
main- 
tenance 
and 


Interest 
(including 




charges are 
payable 


rection 

for power 

factor 




adminis- 
trative 
expenses 


exchange) 




$ c. 




$ c 


$ c. 


$ c 


Orangeville R.P.D. — Amaranth, Cale- 












don, Erin and Garafraxa E. twps. . . 


12,617.89 


32.3 


37.41 


561.23 


595.34 


Owen Sound R.P.D.— Derby, Sara- 












wak and Sydenham twps 


6,379.75 


24.3 


28.15 


302.77 


306.99 


Port Perry R.P.D. — Cartwright, Man- 












vers, Reach and Scugog twps 


42,916.32 


105.7 


122.44 


2,414.01 


2,046.95 


Ripley R.P.D. — Huron and Kinloss 












twps 


4,542.12 


10.1 


11.70 


200.33 


217.69 


Sauble R.P.D.— Amabel and Keppel 












twps 


8,671.21 


16.5 


19.11 


377.05 


417.68 


Shelburne R.P.D.— Amaranth, Mel- 












ancthon and Mulmur twps 


9,533.54 


25.7 


29.77 


620.45 


453.96 


Sparrow Lake R.P.D. — Matchedash, 












Morrison, Orillia N. and Rama twps. 


28,165.67 


105.7 


122.44 


1,202.51 


1,336.90 


Water heater load 




0.1 




*3.30 




Tara R.P.D. — Amabel, Arran, Derby 








and Keppel twps 


17,474.28 


48.1 


55.72 


906.57 


832.09 


Thornton R.P.D. — Essa twp 


7,285.22 


13.1 


15.17 


336.34 


349.43 


Utterson R.P.D.— Cardwell, Hum- 












phrey, Stephenson, Watt, and Wood 












and Medora twps 


20,000.39 


50.7 




815.82 


958.68 


Uxbridge R.P.D. — Brock, Georgina, 












Reach, Scott and Uxbridge twps 


39,501.46 


93.3 


108.07 


1,953.15 


1,882.75 


Wasaga Beach R.P.D.— Flos, Notta- 












wasaga and Sunnidale twps 


51,169.79 


168.1 


194.72 


2,562.45 


2,426.52 


Wroxeter R.P.D. — Howick, Morris 












and Turnberry twps 


50,996.87 


97.0 


112.36 


2,081.30 


2,433.22 


To als — Municipalities. . 


6,157,625.18 


20,026 4 


21,313.30 


311,549.97 


291,396.66 


Water heater loads 




31.3 


♦1,235.85 




Totals — Rural Power Districts 


814,397.93 


2,391.1 


3,909.75 


39,548.10 


38,869.19 


Watc heater loads 




3.6 




*124.25 




Totals — Companies and distributing 






systems 


620,329.47 


1,807.3 


2,093.47 


30,705.87 


29,824.63 




7,592,352.58 




Non-operating capital 


8,514.50 


















Grand totals 


7,600,867.08 


24,259.7 


27,316.52 


383,164.04 


360,090.48 



*Heater costs written off in vear to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



221 



SYSTEM 



G.B.—COST OF POWER 



the Power Commission Act — of Power supplied to it by the Commission; the amount 
and the amount remaining to be credited or charged to each Municipality 
of power supplied to it in the year ending October 31, 1933 



costs and fixed charges 


Cost in 
excess of 

revenue 
from power 

sold to 

private 
companies 


Total cost 

of power 

for year as 

provided to 

be paid 

under 

Power 

Commission 

Act 


Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 






Renewals 


Obsoles- 
cence and 
contin- 
gencies 


Sinking 
fund 


Amounts remaining to 
be credited or charged 
to each municipality 
upon ascertainment of 
the actual cost of power 
by annual adjustment 




Credited j Charged 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


180.41 


45.04 


131.66 


24.92 


1,576.01 


1,576.01 


see page 


225 


75.06 


23.68 


67.11 


18.74 


822.50 


822.50 


a 


" 


628.12 


144.84 


450.73 


81.54 


5,888.63 


5,888.63 


u 


u 


69.04 


15.61 


47.82 


7.79 


569.98 


569.98 


« 


" 


137.81 


31.25 


91.29 


12.73 


1,086.92 


1,086.92 


a 


u 


134.32 


36.50 


99.90 


19.82 


1,394.72 


1,394.72 


u 


U 


335.14 


112.30 


296.47 


81.54 


3,487. 30\ 
3.30/ 


3,490.60 


a 


a 


245.64 
117.38 


70.41 
26.94 


183.95 
76.67 


37.10 
10.11 


2,331.48 
932.04 


2,331.48 
932.04 


a 


a 
a 


290.43 


72.06 


210.48 


39.11 


2,386.58 


2,386.58 


a 


u 


587.12 


133.68 


415.06 


71.97 


5,151.80 


5,151.80 


u 


u 


660.46 


195.17 


538.61 


129.67 


6,707.60 


6,707.60 


a 


a 


807.05 


178.96 


535.05 


74.82 


6,222.76 


6,222.76 


a 


a 


79,625.63 


22,439.34 


64,767.20 


15,448.03 


806,540.131 

1,235.85/ 

107,003. 41\ 

124.25/ 

62,987.29 


863,748.55 
107,127.66 

62,987.29 


61,309.81 


5,337.24 


11,218.68 


3,047.97 


8,565.25 


1,844.47 










8,376.91 


2,770.98 


6,507.93 


(17,292.50) 




99,221.22 


28,258.29 


79,840.38 




977,890.93 


1,033,863.50 















222 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



GEORGIAN BAY SYSTEM— 

Statement showing the costs of distribution of power within each Rural Power 
and the amounts remaining to be credited to certain Districts or charged to 

annual adjustment) of the actual costs 



District and municipalities 
comprised therein 



Total capital cost of each district, 
Provincial Government grant 
received and applied thereagainst, 
and the balance representing the 
investment by the Commission 



Total 

capital 

cost 



Govern- 
ment 
grant 



Com- 
mission's 
investment 



Cost of 

power 
delivered 
to districts 
as shown 
in "cost of 

power" 

table 
preceding 



Alliston R.P.D. — Essa, Tecumseth and Tos- 
sorontio twps 

Arthur R.P.D.— Luther E. and Luther W. 
twps 

Bala R.P.D.— Wood and Medora twp 

Barrie R.P.D. — Innisfil, Oro and Vespra twps. . 

Baysville R.P.D. — Franklin, Macaulay, Mc- 
Lean, Ridout and Sherbourne twps 



Beaumaris R.P.D. — Macaulay, Monck, 

Muskoka, Wood and Medora twps 

Beaverton R.P.D. — Brock, Georgina, Mara 

and Thorah twps 

Beeton R.P.D. — Tecumseth twp 

Bradford R.P.D. — Gwillimbury W., King and 

Tecumseth twps 

Bruce R.P.D. — Brant, Carrick, Culross, 

Greenock and Saugeen twps 



Matchedash, Wood and 
-Brock, Eldon and Mari- 



Buckskin R.P.D 

Medora twps 

Canning ton R.P.D 

posa twps 

Chatsworth R.P.D.— Holland twp 

Cookstown R.P.D. — Essa and Innisfil twps. . . 
Creemore R.P.D. — Nottawasaga, Osprey, 

Sunnidale and Tossorontio twps 



Elmvale R.P.D. — Flos, Medonte, Oro and 
Vespra twps 

Flesherton R.P.D. — Artemesia twp 

Gravenhurst R.P.D.— Muskoka twp 

Hawkestone R.P.D. — Orillia and Oro twps. . . . 

Holstein R.P.D. — Bentinck, Egremont and 
Normanby twps 



Huntsville R.P.D.— Brunei, Chaffey and 

Franklin twps 

Innisfil R.P.D. — Gwillimbury W. and Innisfil 

twps 

Lucknow R.P.D. — Kinloss twp 

Mariposa R.P.D. — Brock, Mariposa and Reach 

twps 

Markdale R.P.D. — Artemesia, Euphrasia, 

Glenelg and Holland twps 



$ c 

38,476.46 

*4,303.91 
*62,316.35 
122,538.62 

68,729.20 

66,062.87 

*57,360.58 
3,018.23 

37,348.15 

♦58,770.96 

4,078.59 

♦19,300.43 

1,414.37 

704.54 

♦45,796.11 



39,707.49 

♦5,286.73 

4,960.99 

44,823.40 

1,897.34 



47,521.93 

78,694.24 
637.09 

76,123.16 

♦28,470.47 



$ 


c. 


18,986 


95 


2,105 
30,274 
61,269 


26 
16 
31 


34,364 


60 


33,031 


44 


28,400 
1,509 


68 
11 


18,509 


01 


27,769 


19 


2,039 


29 


8,033 
707 

352 


14 
19 

27 


22,234.97 


19,720 
2,456 
2,480 

22,411 


57 
59 
49 
70 


948 


67 


23,760 


96 


39,347 
318 


12 

55 


38,061 


58 


14,109 


17 



$ 


c. 


19,489 


51 


2,198 


65 


32,042 


19 


61,269.31 


34,364 


60 


33,031 


43 


28,959 


90 


1,509 


12 


18,839 


14 


31,001 


77 


2,039 


30 


11,267 


29 


707 


18 


352 


27 


23,561 


14 


19,986 


92 


2,830 


14 


2,480 


50 


22,411 


70 


948 


67 


23,760.97 


39,347 


12 


318 


54 


38,061 


58 


14,361 


30 



$ c. 

3,686.71 

174.23 
3,707.79 
9,880.97 

2,552.02 

4,516.92 

5,918.53 
255.10 

2,526.62 

4,777.52 

683 . 14 

1,568.53 

622.40 

39.85 

2,466.88 



2,493.88 
330 . 70 
736.67 

1,793.46 



1,479.95 
8,557.46 

5,605.07 
1,425.85 



Note. — Items marked • include portions of transmission lines aggregating $10,279,48 
used for purposes of rural power districts. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



223 



RURAL POWER DISTRICTS 



G.B.—R URA L OPERA TING 



District, the revenues collected from (or charged to) customers within each District, 
the Municipalities comprising certain other Districts upon ascertainment (by 
in the year ending October 31, 1933. 



Distribution costs and fixed charges 



Cost of 
operation, 
mainten- 
ance and 
adminis- 
tration 



Interest 
(including 
exchange) 



Renewal 
charges 



Obsoles- 
cence and 
contin- 
gencies 



Sinking 
fund 



Total 
cost 



Revenue 

from 
power and 

light 

customers 

in each 

district 



Amounts remaining 
to be credited to 
certain districts or 
charged to the 
municipalities com- 
prising certain other 
districts 



Credited 



Charged 



$ c 

1,766.49 

46.32 
4,425.21 
4,633.04 

1,659.35 

3,128.55 

3,539.31 
89.56 

1,216.08 

2,204.34 

239.26 

709.39 

123.86 

5.93 

1,305.48 



1,572.80 
271.15 
256.73 

1,408.31 

21.78 



1,173.28 

3,566.40 

32.58 

2,903 . 13 

1,051.22 



$ 


c. 


933 


.87 


105 
1,477 
2,891 


96 
91 
.15 


1,632 


80 


1,491 


80 


1,339 

72 


19 
67 


907 


95 


1,232 


88 


88.98 


543.73 
34.09 
16.98 


1,133 


15 


963 

135 

113 

1,068 


95 
80 
22 
00 


44.96 


970.05 


1,778 
15 


82 
19 


1,813.04 


659.95 



$ c. 


$ c. 


$ c. 


764.03 


764.03 


203.77 


85.96 
1,189.68 
2,396.47 


85.96 
1,189.68 
2,396.47 


23.12 
322.48 
630.87 


1,353.42 


1,353.42 


356.29 


1,236.55 


1,236.55 


325.52 


1,100.29 
60.24 


1,100.29 
60.24 


292.22 
15.86 


746.00 


746.00 


198.13 


958.88 


958.88 


269.03 


73.76 


73.76 


19.42 


386.01 
28.26 
14.07 


386.01 
28.26 
14.07 


118.65 

7.44 
3.70 


912.73 


912.73 


247.27 


793.69 

105.09 

93.85 

885.26 


793.69 

105.09 

93.85 

885.26 


210.34 
29.63 
24.70 

233.05 


37.34 


37.34 


9.83 


804.07 


804.07 


211.67 


1,474.46 
12.74 


1,474.46 
12.74 


388.15 
3.35 


1,502.82 


1,502.82 


395.62 


541.98 


541.98 


144.01 



$ c 

8,118.90 

521.55 
12,312.75 
22,828.97 

8,907.30 

11,935.89 

13,289.83 
553.67 

6,340.78 

10,401.53 

1,178.32 

3,712.32 

844.31 

94.60 

6,978.24 

6,828.35 

977.46 

1,319.02 

6,273.34 

151.25 

5,443.09 

17,239.75 
76.60 

13,722.50 

4,364.99 



$ c. 
8,432.03 


$ 
313 
104 


c. 

13 

37 


$ c. 


625.92 
9,660.41 


2,652 '34 


21,185.61 




1,643.36 


4,737.17 




4,170 13 


12,255.92 


320 


03 




10,568.20 


2,721.63 


327.95 




225.72 


4,401.56 




1,939.22 


10,633.12 


231 


59 




946 . 73 


231.59 


4,085.51 


373 


19 




789.36 


54. 95 


144.54 


49 


94 




4,868.29 


2,109.95 


6,595.87 




232.48 


826.26 




151.20 


1,143.58 




175.44 


5,247.27 




1,026.07 


80.25 




71 00 


3,674.81 




1,768.28 


16,796.94 




442.81 


51.22 




25.38 


14,667.67 


945 


17 




3,567.20 


797.79- 











224 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



GEORGIAN BAY SYSTEM— 

Statement showing the costs of distribution of power within each Rural Power 
and the amounts remaining to be credited to certain Districts or charged to 

annual adjustment) of the actual costs 



District and municipalities 
comprised therein 



Total capital cost of each district, 
Provincial Government grant 
received and applied thereagainst, 
and the balance representing the 
investment by the Commission 



Total 

capital 

cost 



Govern- 
ment 
grant 



Com- 
mission's 
investment 



Cost of 

power 

delivered 

to districts 

as shown 

in ''cost of 

power" 

table 

preceding 



Meaford R.P.D. — St. Vincent twp 

Medonte R.P.D. — Baxter and Tay twps 

Midland R.P.D. — Tay and Tiny twps 

Neaustadt R.P.D. — Bentinck twp 

Nottawasaga R.P.D. — Nottawasaga twp 

Orangeville R.P.D. — Amaranth, Caledon, Erin 
and Garafraxa E. twps 

Owen Sound R.P.D. — Derby, Sarawak and 
Sydenham twps 

Port Perry R.P.D. — Cartwright, Manvers, 
Reach and Scugog twps 

Ripley R.P.D. — Huron and Kinloss twps 

Sauble R.P.D. — Amabel and Keppel twps 

Shelburne R.P.D. — Amaranth, Melancthon 

and Mulmur twps 

Sparrow Lake R.P.D. — Matchedash, Morrison, 

Orillia N. and Rama twps 

Tara R.P.D. — Amabel, Arran, Derby and 

Keppel twps 

Thornton R.P.D. — Essa twp 

Utterson R.P.D. — Cardwell, Humphrey, 

Stephenson, Watt and Wood and Medora twps. 

Uxbridge R.P.D. — Brock, Georgina, Reach, 
Scott and Uxbridge twps 

Wasaga Beach R.P.D. — Flos, Nottawasaga 
and Sunnidale twps 

Wroxeter R.P.D. — Howick, Morris and Turn- 
berry twps 

Non-operating capital 

Totals 



$ c. 

1,971.26 
17,479.52 
17,075.95 

1,041.69 
16,816.07 



33,300.97 

12,768.57 

73,453.44 

*8,511.30 

4,338.83 



26,230 

75,845 

30,321 
9,479 



'39,684.03 



84,696 
57,516 
74,612 



1,503,485. 
2,872. 



,506,358.32 



$ c. 

985.63 
8,739.76 
8,537.97 

520.84 
8,408.04 



16,650.49 

6,384.29 

36,726.72 
3,984.83 
2,169.42 

12,497.02 

37,922.58 

15,160.66 
4,739.56 

19,047.37 
42,348.26 



35,925.80 



713,951.21 
1,436.37 



715,387.58 



$ c. 

985.63 
8,739.76 
8,537.98 

520.85 
8,408.03 



16,650.48 

6,384.28 

36,726.7? 
4,526.47 
2,169.41 

13,733.18 

37,922.58 

15,160.66 
4,739.56 

20,636.66 

42,348.26 
57,516.97 
38,686.65 



789,534.37 
1,436.37 



790,970.74 



807.68 
817.42 



1,140.69 

1,576.01 

822.50 

5,888.63 

569.98 

1,086.92 

1,394.72 

3,490.60 

2,331.48 
932.04 

2,386.58 

5,151.80 
6,707.60 
6,222.76 



107,127.66 



Note. — Items marked * include portions of transmission lines aggregating $10,279.48 used 
for purposes of rural power districts. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



225 



RURAL POWER DISTRICTS 



G.B.—R URA L PE RA TING 



District, the revenues collected from (or charged to) customers within each District, 
the Municipalities comprising certain other Districts upon ascertainment (by 
in the year ending October 31, 1933. 



Distribution 


costs and fixed charges 


Cost of 










operation, 
mainten- 
ance and 
adminis- 


Interest 
(including 
exchange) 


Renewal 
charges 


Obsoles- 
cence and 
contin- 
gencies 


Sinking 
fund 


tration 











Total 
cost 



Revenue 

from 
power and 

light 

customers 

in each 

district 



Amounts remaining 
to be credited to 
certain districts or 
charged to the 
municipalities com- 
prising certain other 
districts 



Credited 



Charged 



* c. 

7.45 
462.46 
412.82 

3.97 
664.94 



815.57 

651.80 

2,434.95 
186.69 
523.19 

1,302.81 

2,144.95 

1,689.70 
112.25 

1,348.43 

2,065.89 
2,346.97 
2,320.33 



$ c. 

46.99 
411.18 
411.52 

24.87 
404.21 



802 . 25 

165.15 

1,722.69 
209.89 
100.14 

656.13 

1,788.64 

720.06 
228.71 

923 64 

2,029.14 
2,629.08 
1,859.81 



$ c. 

39.12 
340.83 
341.11 

20.75 
335.05 



664.98 

136.89 

1,427.93 

163.14 

83.00 



519.14 

1,482.60 

596.86 
189.58 

733.86 

1,681.95 
1,089.62 
1,486.38 



$ c. 

39.12 
340.83 
341.11 

20.75 
335.05 



664.98 

136.89 

1,427.93 

163.14 

83.00 



519.14 

1,482.60 

596.86 
189.58 

733.86 

1,681.95 
1,089.62 
1,486.38 



$ c. 
10.30 
89.72 
89.80 

5.46 
88.20 



175.06 

36.04 

375.90 
45.80 
21.85 

143.18 

390.30 

157.12 
49.90 

201.54 

442.77 
573.68 
405.82 



$ c. 

142.98 

2,452.70 

2,413.78 

75.80 

2,968.14 



4,698.85 

1,949.27 

13,278.03 
1,338.64 
1,898 : 10 

4,535.12 

10,779.69 

6,092.08 
1,702.06 

6,327.91 

13,053.50 
14,436.57 
13,781.48 



$ c 

81.20 

1,747.20 

1,975.37 

29.47 

3,188.29 



3,622.89 

1,382.78 

11,988.36 

758.98 

1,356.15 

2,800.73 

9,701.29 

5,465.83 
1,272.16 

6,343.24 

10,006.50 

14,958.31 
13,407.34 



220.15 



15.33 



521.74 



$ c. 

61.78 
705.50 
438.41 

46.33 



1,075.96 

566.49 

1,289.67 
579.66 
541.95 

1,734.39 

1,078.40 

626.25 
429.90 



3,047.00 



374.14 



56,844.72 



36,600.19 



28,890.44 



28,890.44 



7,986.56 



266,340.01 



236,399.48 



3,094.64 



33,035.17 



226 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



GEORGIAN BAY 

Statement showing the net Credit or Charge to each Municipality in respect of power 

made and interest added during the year. Also the net amount Credited 

ending October 31, 1933, and the accumulated amount standing 



Municipality 



Date 

commenced 

operating 



Net credit or charge at 
October 31, 1932 



Cash receipts and pay- 
ments on account of 
such credits and charges, 
also adjustments made 
during the year 



Credit Charge 



Credited | Charged 



Alliston 

Arthur 

Barrie 

Beaverton 

Beeton 

Bradford 

Brechin 

Cannington .... 
Chatsworth .... 
Chesley 

Coldwater 

Collingwood. . . . 

Cookstown 

Creemore 

Dundalk 

Durham 

Elmvale 

Elmwood 

Flesherton 

Grand Valley. . . 

Gravenhurst .... 

Hanover 

Holstein 

Huntsville 

Kincardine 

Kirkfield 

Lucknow 

Markdale 

Meaford 

Midland 

Mildmay 

Mount Forest . . 

Neustadt 

Orangeville 

Owen Sound .... 

Paisley 

Penetanguishene 

Port Elgin 

Port McNicoll. . 
Port Perry 

Priceville 

Ripley 

Rosseau 

Shelburne 

Southampton. . . 



June, 


1918 


Dec, 


1916 


April, 


1913 


Nov., 


1914 


Aug., 


1918 


Oct., 


1918 


Jan., 


1915 


Nov., 


1914 


Dec, 


1915 


July, 


1916 


Mar., 


1913 


Mar., 


1913 


May, 


1918 


Nov., 


1914 


Dec, 


1915 


Dec, 


1915 


June, 


1913 


April, 


1918 


Dec, 


1915 


Dec, 


1916 


Nov., 


1915 


Sept., 


1916 


May, 


1916 


Sept., 


1916 


Mar., 


1921 


June, 


1920 


Jan., 


1921 


Mar., 


1916 


Jan., 


1924 


July, 


1911 


Dec, 


1932 


Dec, 


1915 


Dec, 


1918 


July, 


1916 


Dec, 


1915 


Sept., 


1923 


July, 


1911 


Mar., 


1931 


Jan., 


1915 


Sept., 


1922 


Mar., 


1920 


Jan., 


1921 


Tuly, 


1931 


luly, 


1916 


Feb., 


1931 



$ c 
1,326.03 



570.36 
581.97 

588.52 
237.63 
480.20 



2,305.35 

538.24 
455 . 16 
259.75 
527.83 



438.90 
646.92 



1,918.30 

2,255.17 



688 . 78 
1,018.49 



69.42 
342.62 



402.13 
308.38 



146.87 

275.51 

82.22 

486.70 



1,550.64 
10,637.05 



92.27 



93.64 



1,758.80 



211.08 
741.69 

2,310.44 

750.90 

3.035.43 



209.61 

"66.59 

5.566.22 



2,673.32 
4,547.61 



1.110.25 



516.48 
238.80 

20.20 



$ c 



567.52 



8.83 



92.27 



385.18 



1,758.80 



211.08 
741.69 



750.90 
609.85 



66.59 



5,560.22 



2.673.32 



1,110.25 



238.80 
20.20 



$ c 
1.326.03 



570.36 
581.97 

597.35 
237.63 
480.20 



2,305.35 

538.24 
840.34 
259.75 
527.83 



438.90 
646.92 



1,918.30 
2,255.17 



688.78 



1,018.49 



69.42 
342.62 



402.13 
308.38 



146.87 

275.51 

82.22 

486.70 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



227 



SYSTEM 



G.B.— CREDIT OR CHARGE 



supplied to it to October 31, 1932; the cash receipts and payments thereon, adjustments 
or Charged to each Municipality in respect of power supplied in the year 
as a Credit or Charge to each Municipality at October 31, 1933. 



Interest at 4 % per annum 
added during the year 



Credited 



Charged 



Net amount credited or charged 
in respect of power supplied in 
the year ending October 31, 1933 



Credited Charged 



Accumulated amount standing 

as a credit or charge on 

October 31, 1933 



Credit Charge 



$ c. 
13 51 


$ c. 


$ c. 
1,546.06 

596.08 
7,126.16 

207.36 

927.47 

1,336.32 
322.64 
466.76 


$ c. 


$ c. 
1,559.57 


$ c. 




62.03 
409.81 




1,016.59 








3,353.18 


7 06 




214.42 
935.76 

1,346.08 
326.57 
473.55 


8 29 








9 76 








3 93 








6 79 










1.31 


80.18 


81.49 


32 37 


1,870.47 


1,902.84 




7 91 




371.13 


363 22 


11.33 




509.59 
465.90 


520.92 
469.49 




3.59 








7.00 




28.37 


21.37 




3.75 
33.92 


571.75 

1,354.58 
533.23 
536.74 
289.58 
550.17 

1,343.89 
2,223.89 


474.36 

1,320.66 
541.09 

545.45 
285.81 
538.22 










7.86 






8.71 










3.77 
11.95 

92.42 

11.36 

110.88 
















1,058.97 






2,212.53 




378.37 
2,807.25 


2,914.83 


25.65 






2,781.60 


30.18 




3,636.99 


3,667.17 




8.38 


30.03 


248.02 


9.59 


1,043.64 

533.08 

1,085.96 

7,031.72 

915.32 
1,394.51 


1,053.23 

532.20 

1,099.69 

6,948.24 

915.32 
1,358.48 






0.88 






13.73 








83.48 














36.03 
181.90 








1,195.50 


5,925.01 


1.15 


829.50 
10,567.82 

270.30 
2,002.80 
317.49 
304.28 
219.24 

350.05 
374.05 
747.85 


830.65 
10,572.81 

247.79 

2,008.71 

321.85 


4.99 










22.51 






5.91 






4.36 










20.66 
3.38 

0.38 




232.86 






215.86 

349.67 
376.00 
751.50 










1.95 






3.65 








1.05 




107.03 


105.98 


6.35 




459.73 


466.08 





228 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



GEORGIAN BAY 

Statement showing the net Credit or Charge to each Municipality in respect of power 

made and interest added during the year. Also the net amount Credited 

ending October 31, 1933, and the accumulated amount standing 



Municipality 


Date 

commenced 

operating 


Net credit or charge at 
October 31, 1932 


Cash receipts and pay- 
ments on account of 
such creditsand charges, 
also adjustments made 
during the year 




Credit 


Charge 


Credited | Charged 


Stayner 


Oct., 1913 
Nov., 1914 
Feb., 1918 
Dec, 1920 
Nov., 1918 

Oct., 1918 
Sept., 1922 
July, 1914 
Feb., 1931 
Dec, 1914 

May. 1931 
June, 1930 
Dec, 1920 
Nov., 1914 

Nov. 1929 
Dec, 1929 
Jan., 1930 
Aug., 1923 
July, 1932 

June, 1928 
Aug., 1930 
Sept., 1976 
Aug., 1929 
Oct., 1931 

July, 1928 
May, 1924 
Dec, 1928 
Dec, 1930 
Dec, 1930 

Jan., 1924 
Feb., 1922 
June, 1929 
Aug., 1930 
Mar., 1929 

Aug., 1931 
Feb., 1928 
Feb., 1924 
Sept., 1923 
July, 1924 

Oct., 1928 
July, 1930 
Nov., 1930 
Nov., 1926 
Jan., 1922 


$ c. 
473.62 


$ c 


$ c 


$ c 
473.62 


Sunderland 


233.87 


233.87 




Tara 


393.59 


393.59 


Teeswater 


208.81 






Thornton 


273.64 




273.64 


Tottenham 


280.14 


282.48 


2.34 


Uxbridge 

Victoria Harbour 


349.36 

74.58 

361.19 

213.14 

617.71 
764.13 
116.38 

36.72 

1,565.32 


349.36 






74.58 


Walkerton 






361.19 


Waubaushene 






213.14 


Wiarton 






617.71 


Windermere 






764.13 


Wingham 






116.38 


Woodville 






36.72 


Rural Power District* 
Alliston R.P.D 






80.00 


Arthur R.P.D 


124.67 
3,160.26 
4,129.32 
1,639.98 

1,658.96 
3,701.19 

178.94 
1,921.23 

944.11 

822.76 






Bala R.P.D 






120.00 


Barrie R.P.D 






130.00 


Baysville R.P.D 

Beaumaris R.P.D 












30.00 


Beaverton R.P.D 






120.00 


Beeton R.P.D 








Bradford R.P.D 






175.86 


Bruce R.P.D 






20.00 


Buckskin R.P.D. . 






30.00 


Cannington R.P.D 

Chatsworth R.P.D . 


1,742.48 

325.63 

42.08 










90.00 


Cooks town R.P.D 








Creemore R.P.D 


2,508.92 

389.01 
837.92 




140.00 


Elmvale R.P.D. . 




40.00 


Flesherton R.P.D 


' 230 .64 






Graven hurst R P D 






Hawkestone R.P.D 


2,665.71 
79.96 

2,477.26 

3,071.06 

74.66 






HoJstein R P D 








Huntsville R P.D 








Innisfil R.P.D. 






138.30 


Lucknow R P D 








Mariposa R.P.D 

Markdale R P D 


5,077.42 




40.00 


1,363.18 

133.04 

1,113.53 

892.28 

97.84 


1.36 




Meaford R P.D 






Medonte R P D 






50.00 


Midland R P D 






80.00 


Neustadt R P D 








Nottawasaga R.P.D 


1,040.95 







*For townships included in rural power districts see "Cost of Power" and "Rural Operating' 
statements preceding. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



229 



SYSTEM 



G.B. —CREDIT OR CHARGE 



supplied to it to October 31, 1932; the cash receipts and payments thereon, adjustments 
or Charged to each Municipality in respect of power supplied in the year 
as a Credit or Charge to each Municipality at October 31, 1933. 



Interest at 4% per annum 
added during the year 



Credited Charged 



Net amount credited or charged 
in respect of power supplied in 
the year ending October 31, 1933 



Credited 



Charged 



Accumulated amount standing 

as a credit or charge on 

October 31, 1933 



Credit Charge 



$ c. 
6 70 


$ c. 


$ c. 
464.21 
203.68 
605.86 
404.59 
268.50 

790.67 

526.80 

354.90 

1,518.33 

91.44 


$ c. 


$ c. 
470.91 
200.17 
611.90 
187.43 
271.29 

783.06 

532.58 

356.00 

1,524.03 

95.17 


$ c. 




3.51 






6.04 








8.35 






2 79 








7.61 






5 78 






1 10 








5.70 








3.73 








8.26 




339.38 


331.12 


10.13 




750.66 
299.95 
167.25 

313.13 
104.37 


760.79 
301.53 
167.77 

1,861.06 




1.58 








0.52 








62.61 










4.99' 

126.41 

165.17 

65.60 

66.36 

148.05 

7.16 

77.78 
37.76 

32.91 




25.29 




2,652.34 
1,643.36 
4,170.13 




6,059 01 








6,067 85 








5,875.71 




320.03 




1,435.29 




2,721.63 

225.72 

1,939.22 




6,690.87 








411 82 








4,114 09 




231.59 




770 28 




231.59 




1,117 26 


69.70 


373.19 


2,185.37 

193.71 

93.70 




13.03 




54.95 




1.68 




49.94 






100.36 

15.56 
33.52 


2,109.95 

232.48 

151.20 

175.44 

1,026.07 

71.00 

1,768.28 

442.81 

25.38 


4 859 23 








677 05 






. 


1 02? 64 


9.23 




64.43 






106.63 
3.20 

99.09 

122.84 

2.99 




3 798 41 








154 16 








4,344 63 








3 775 01 








103 03 


203.10 


945.17 


6,185.69 






54.49 

5.32 
44.54 
35.69 

3.91 


797.79 

61.78 
705.50 
438.41 

46.33 


2 214 10 








200 14 








1,913.57 
1,446 38 














148 08 


41.64 


220.15 


1,302.74 





230 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



GEORGIAN BAY 

Statement showing the net Credit or Charge to each Municipality in respect of power 

made and interest added during the year. Also the net amount Credited 

ending October 31, 1933, and the accumulated amount standing 



Rural power district 



Date 

commenced 

operating 



Net credit or charge at 
October 31, 1932 



Credit Charge 



Cash receipts and pay- 
ments on account of 
such creditsand charges, 
also adjustments made 
during the year 



Credited | Charged 



Orangeville R.P.D 


Aug., 
Mar., 
Dec, 
Feb., 
Oct., 

Feb., 
Oct., 
Jan., 
Aug., 
June, 

Sept., 

July, 

Feb., 


1927 
1931 
1922 
1922 
1931 

1926 
1925 
1925 
1930 
1930 

1925 
1923 
1929 


$ c. 


$ c. 
3,467.39 

91.36 

3,644.57 

1,118.90 

197.64 

1,867.13 


$ c. 


$ c. 


Owen Sound R.P.D 








Port Perry R.P.D 






250.00 


Ripley R.P.D 




20.00 


Sauble R.P.D 




40.00 


Shelburne R.P.D 




180.00 


Sparrow Lake R.P.D 


997.46 


130.48 


Tara R.P.D 


147.73 

753.53 

1,248.10 

6,768.20 




20.00 


Thornton R.P.D 






140.00 


Utterson R.P.D 






110.00 


Uxbridge R.P.D 






210.00 


Wasaga Beach R.P.D 


10,643.48 


361.43 


Wroxeter R.P.D 


4,366.12 




30.00 








Totals 




42,290.97 


94,504.30 


15,313.21 


23,797.93 











*For townships included in rural power districts see "Cost of Power" and "Rural Operating' 
statements preceding. 



GEORGIAN BAY SYSTEM 
Reserve for Renewals— October 31, 1933 

Total provision for renewals to October 31, 1932 $1,431,214. 29 

Deduct: 

Expenditures to October 31, 1932 133,155.81 

Balance brought forward October 31, 1932 $1,298,058.48 

Added during the year ending October 31, 1933: 

Amounts charged to municipalities and rural power districts as 

part of the cost of power delivered to them $90,844 .31 

Amount included in costs of distribution of power within rural 

power districts 28,890 . 44 

Provision against equipment employed in respect of contracts 

with private companies which purchased power, and against 

equipment in local distribution systems 8,376.91 

Provision for renewals on transmission lines transferred 3,531 .40 

Interest at 4 % per annum on monthly balances at the credit of 

the account 51.922 .34 

183,565.40 

$1,481,623.88 
Deduct: 

Expenditures during the year ending October 31 , 1933 27,403 . 29 

Balance carried forward October 31, 1933 $1,454,220.59 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



23 



SYSTEM 



G.B.— CREDIT OR CHARGE 



supplied to it to October 31, 1932; the cash receipts and payments thereon, adjustments 
or Charged to each Municipality in respect of power supplied in the year 
as a Credit or Charge to each Municipality at October 31, 1933. 



Interest at 4 % per annum 
added during the year 



Credited Charged 



Net amount credited or charged 
in respect of power supplied in 
the year ending October 31, 1933 



Credited 



Charged 



Accumulated amount standing 

as a credit or charge on 

October 31, 1933 



Credit 



Charge 



$ c. 


$ c. 
138.70 

3.65 

145.78 

44.76 

7.91 

74.69 


$ c. 


$ c. 
1,075.96 

566.49 
1,289.67 

579.66 

541.95 

1,734.39 

1,078.40 

626 . 25 

429.90 


$ c. 


$ c. 
4,682.05 








661.50 








5,330.02 








1,763.32 








787.50 








3,856.21 


39 87 






171.55 




5.91 
30.14 
49.92 

270.73 






799 . 89 








1,353.57 




15.33 




1,392.69 




3,047.00 




10,295.93 


424.35 


521.74 


11,228.14 






174.64 


374.14 


4,944.90 










1,154.21 


3,425.43 


64,404.45 


38,372.41 


74,760.04 


111,697.27 



GEORGIAN BAY SYSTEM 
Reserve for Obsolescence and Contingencies — October 31, 1933 

Balance brought forward October 31, 1932 $367,197.47 

Added during the year ending October 31, 1933: 

Amounts charged to municipalities and rural power districts as 

part of the cost of power delivered to them $25,487 .31 

Amounts included in the costs of distribution of power within 

rural power districts 28,890 . 44 

Provision against equipment employed in respect of contracts 

with private companies which purchased power and against 

local distribution systems 2,770 .98 

Share of profits realized in respect of the sale of certain of the 

Commission's investment securities 1,304.69 

Interest at 4 % per annum on monthly balances at the credit of 

the account 14,687 .90 

73,141.32 

$440,338.79 
Deduct: 

Contingencies met with during the year ending October 3 1 , 1933 . . $1,311.20 
Commission's share of American exchange paid during the year 
by the Province of Ontario on the transfer of funds to New 
York to meet capital retirements 9,191 . 27 

10,502.47 

Balance carried forward October 31, 1933 $429,836 .32 



232 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



GEORGIAN BAY SYSTEM G.B.— SINKING FUND 

Statement showing Sinking Fund paid by each Municipality in the periods mentioned 

hereunder, as part of the cost of power delivered thereto, together with its 

proportionate share of other sinking funds provided out of other 

revenues of the system, and interest allowed thereon to 

October 31, 1933 



Municipality 



Period 
of years 

ending 

Oct. 31, 

1933 



Amount 



Municipality 



Period 
of years 

ending 

Oct. 31, 

1933 



Amount 



Alliston . . 
Arthur. . . 
Barrie. . . . 
Beaverton 
Beeton. . . 



Bradford . . . 
Brechin . . . . 
Cannington 
Chatsworth 
Chesley . . . . 



Coldwater. . 
Collingwood 
Cookstown . 
Creemore. . . 
Dundalk. . . 



Durham 

Elm vale 

Elmwood. . . . 
Flesherton. . . 
Grand Valley 

Gravenhurst . 
Hanover .... 

Holstein 

Huntsville. . . 
Kincardine . . 



Kirkfield . 
Lucknow . 
Markdale. 
Meaford. . 
Midland. . 



Mildmay 

Mount Forest. 

Neustadt 

Orangeville . . . 
Owen Sound . . 



Paisley 

Penetanguishene 

Port Elgin 

Port McNicoll . . 
Port Perry 



Priceville. . . . 

Ripley 

Rosseau 

Shelburne. . . 
Southampton 



Stayner . . . 
Sunderland 

Tara 

Teeswater . 
Thornton. . 



Tottenham 

Uxbridge 

Victoria Harbour. 



10 years 

12 " 
15 " 
14 " 
10 " 

10 " 

14 " 

14 " 

13 " 

12 " 

15 " 
15 " 
10 " 

14 " 

13 " 

13 " 

15 " 
10 " 
13 " 

12 " 

13 " 
12 " 
12 " 
12 " 

9 " 

9 " 

9 " 

12 " 
9 " 

15 " 

1 " 

13 " 
10 " 

12 " 

13 " 

9 " 

17 " 

3 " 

14 " 
9 " 

9 " 

9 " 

3 " 

12 " 

3 " 

15 " 
14 " 
10 " 

9 " 

10 " 

10 " 

9 " 

14 " 



$ 
11,295 
10,746 
73,212 
12,230 
8,727 

9,628 
4,761 
9,119 

2,277 
18,843 

7,205 
80,932 
2,675 
6,686 
6,385 

17,853 
8,963 
2,053 
3,628 
6,573 

11,934 

45,822 

2,093 

30,684 

18,529 

1,744 

9,186 

5,032 

12,735 

125,095 

226 

16.380 

5,502 

21,353 

101,536 

5,273 
36,078 
1,938 
3,328 
7,789 

838 
3,882 

790 

10,059 

1,993 

8,696 
6,183 
4,661 
6,444 

1,777 

5,592 
8,297 
3,642 



YYalkerton. . . . 
Waubaushene. 



Wiarton. . . . 
Windermere . 
Wingham. . . 
Woodville . . 



Rural Power District* 



Alliston R.P.D 

Arthur R.P.D 

Bala R.P.D 

Barrie R.P.D 

Baysville R.P.D 

Beaumaris R.P.D. . 
Beaverton R.P.D . . . 

Beeton R.P.D 

Bradford R.P.D ... . 
Bruce R.P.D 

Buckskin R.P.D 
Cannington R.P.D. 
Chatsworth R.P.D. 
Cookstown R.P.D. . 
Creemore R.P.D. . . 

Elmvale R.P.D 

Flesherton R.P.D 
Gravenhurst R.P.D 
Hawkestone R.P.D. 
Holstein R.P.D. .. . 

Huntsville R.P.D 

Innisfil R.P.D 

Lucknow R.P.D 
Mariposa R.P.D. .. . 
Markdale R.P.D . 

Meaford R.P.D 

Medonte R.P.D 

Midland R.P.D 
Neustadt R.P.D . . 
Nottawasaga R.P.D 

Orangeville R.P.D . 
Owen Sound R.P.D 
Port Perry R.P.D 

Ripley R.P.D 

Sauble R.P.D 

Shelburne R.P.D 
Sparrow Lake R.P.D 

Tara R.P.D 

Thornton R.P.D. 
Utterson R.P.D. . 

Uxbridge R.P.D. . 
Wasaga Beach R.P.D 
Wroxeter R.P.D. . 

Total 



3 years 
14 " 

3 " 

4 " 
9 " 

14 " 



4 years 

4 " 

4 " 

11 " 

2 " 

6 " 

4 " 
8 " 

5 " 

3 " 

6 " 
10 " 

5 " 

3 " 

3 " 

10 " 

12 " 

5 " 

4 " 

5 " 

3 " 

6 " 
8 " 

11 " 

10 " 

5 " 

4 " 
3 " 

7 " 

12 " 

7 " 

3 " 

11 " 



$ c. 
3,921.66 
2,070.83 

3,047.88 

722.32 

18.287.75 

6,229.56 



1,976.31 

130.92 

2,020.77 

6,471.39 

738.83 

3,490.11 

2,624.49 

80.71 

952.33 

1,467.36 

504.84 
2,739.29 

261.42 

21.98 

1,032.29 

1,852.01 

481.84 

533.05 

836.87 

23.86 

729.67 

4,786.58 

29.42 

6,744.21 

718.05 

41.77 

398.20 

469.16 

28.79 

2,379.25 

1,492.80 
191.42 

3,584.37 
308.03 
218.00 

814.24 
3,903.94 
1,948.59 

413.74 
1,291.77 

3,720.84 
7,276.10 
3,723.65 



936.659.56 



*For townships included in rural power districts see "Cost of Power" and "Rural Operating" 
statements preceding. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



233 



GEORGIAN BAY SYSTEM SINKING FUND 

Reserve for Sinking Fund — October 31, 1933 

Total provision for sinking fund to October 31, 1932 $816,185 .21 

Provided in the year ending October 31, 1933: 

By charges included in the cost of power delivered to munici- 
palities and rural power districts $73,332.45 

By charges included in the costs of distribution of power within 

rural power districts 7,986 . 56 

By charges against contracts with private companies which 

purchased power and local distribution systems 6,507.93 



Interest at 4 % per annum on the amount standing at the credit 

of the reserve accounts 32,647 .41 



120,474.35 



Total $936,659.56 



GEORGIAN BAY SYSTEM— RURAL LINES 

Statement showing Interest, Sinking Fund, Renewals and Contingencies charged by 

the Commission to the Municipalities which operate the respective 

rural lines for the year ending October 31, 1933 



Operated by 


Capital 
cost 


Interest 


Sinking 
fund 


Renewals 


Contin- 
gencies 


Total interest, 

sinking fund, 

renewals and 

contingencies 

charged 


Brechin 

Flesherton 


$ c. 

922.02 

1,885.41 


$ c. 

48.22 

105.77 


$ c. 
16.60 
33.94 


$ c. 
18.44 
37.71 


$ c. 

9.22 

18.85 


$ c. 

92.48 

196.27 


Totals 


2,807.43 


153.99 


50.54 


56.15 


28.07 


288.75 



Statement showing the total Sinking Fund paid in respect of each line, together 
with interest allowed thereon to October 31, 1933 



Lines operated by 


Period of years 

ending 
October 31, 1933 


Amount 


Brechin 


15 years 

16 " 


$ c. 
303 . 80 


Flesherton 


542.61 






Total 




846.41 









Reserve for Sinking Fund 

Total provision for sinking fund to October 31, 1932 $765 . 26 

Provided in year ending October 31, 1933 — 

By charges against municipalities which operate the lines $50 .54 

Interest at 4 % per annum on amounts standing at the credit of the 

reserve accounts 30 . 61 

81.15 



Total 



$846.41 



234 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

GEORGIAN BAY SYSTEM— RURAL LINES 
Reserve for Renewals — October 31, 1933 

Total provision for renewals to October 31, 1932 $443 .27 

Added during the year ending October 31, 1933: 

By charges against the municipalities which operate the lines $56.15 

Interest at 4 % per annum on the monthly balances at the credit of 

the account 17 .73 

73.88 

Balance carried forward October 31, 1933 $517 . 15 



EASTERN ONTARIO 
Operating Account for Year 

Costs of operation as provided under the terms of the Power Commission Act 

Power purchased $777,050.62 

Costs of operation and maintenance, including the proportion of 
administrative expenses chargeable to the operation of the system: 

Generation, transmission and distribution equipment $634,412.70 

Rural power districts 121,212.84 

Water heater costs written off in year to extent of revenue 

available from water heater loads 5,978 .03 

761,603.57 

Interest (including exchange thereon) on capital investment in: 

Generation, transmission and distribution equipment $817,089.21 

Rural power districts 77, 164 . 46 

894,253.67 

Provision for renewals of: 

Generation, transmission and distribution equipment $164,867. 11 

Rural power districts 62,925 .98 

227,793.09 

Provision for obsolescence and contingencies in respect of: 

Generation, transmission and distribution equipment $51,725 .63 

Rural power districts 31,462 .99 

83,188.62 



Provision for sinking funds: 

By charges included in the cost of power delivered to munici- 
palities and rural power districts $1 10,238 . 06 

By charges against contracts with private companies which 

purchased power and local distribution systems 45,928.35 

By charges included in the cost of distribution of power within 

rural power districts 16,863 .37 

173,029.78 

$2,916,919.35 



1934 HYDRO-ELECTRIC POWER COMMISSION 235 

GEORGIAN BAY SYSTEM— RURAL LINES 
Reserve for Obsolescence and Contingencies — October 31, 1933 

Balance brought forward October 31, 1932 $186.82 

Added during the year ending October 31, 1933: 

By charges against the municipalities which operate the lines $28.07 

Interest at 4 % per annum on the monthly balances at the credit of 

the account 7 . 47 

35.54 

Balance carried forward October 31, 1933 $222.36 



SYSTEM 

Ending October 31, 1933 

Revenue for period 

Collected from municipalities under "Cost" contracts at interim 

monthly rates $1,859,103 .83 

Collected from customers in rural power districts 470,228.73 

Power sold to private companies 512,671 .12 

Collected from customers in local electric distribution systems 23,922.25 

Power supplied to pulp miU at Campbellford 38,785 .36 

Collected from customers of the gas works 15,738 .90 

$2,920,450. 19 

Add: 

Amounts due by certain municipalities, being the difference 
between the sums paid and the cost of power supplied to 

them in the year $6,720 . 97 

Amounts due by municipalities comprising certain rural power 
districts, being the difference between the revenue collected 
from customers therein and the cost of power supplied them 

in the year 38,276.43 

44,997.40 



$2,965,447.59 



Deduct : 

Amounts collected from certain municipalities in excess of the 
sums required to be paid by them for power supplied in the 

year $41,852.39 

Amounts collected from customers in certain rural power districts 

in excess of the cost of power delivered thereto 5,394.21 

47,246.60 

Revenue $2,918,200.99 

Deduct: 

Amount transferred to the credit of obsolescence and contingency 
reserve, which amount comprises: 

Profit from power sold to customers on local electric dis- 
tribution systems owned by the Commission $3,453 .91 

Shortage on operation of local gas works 2,172.27 

1,281.64 

$2,916,919.35 



236 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



EASTERN ONTARIO 

Statement showing the amount to be paid by each Municipality as the Cost — under the 

received by the Commission from each Municipality on account of such cost; 

pality upon ascertainment (by annual adjustment) of the actual cost 



Municipality 



Interim rate 

per 
horsepower 
collected by 
Commission 
during year 



To 

Jan. 1 

1933 



To 

Oct. 31 
1933 



Share of 

capital cost 

of system 

on which 

interest and 

fixed charges 

are payable 



Average 
horse- 
power 

supplied 

in year 

after 

correction 

for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



Alexandria 

Apple Hill 

Athens 

Bath 

Belleville 

Water heater load 



Bloomfield 

Bowmanville 

Water heater load 
Brighton 

Water heater load 

Brockville 

Cardinal 

Water heater load 



Carleton Place 

Water heater load 

Chesterville 

Cobourg 

Water heater load 

Colborne 

Deseronto 

Water heater load 



Finch 

Water heater load 

Hastings 

Havelock 

Kemptville 

Lakefield 



Lanark 

Lancaster 

Lindsay 

Water heater load 

Madoc 

Marmora 

Water heater load 

Martintown 

Maxville 

Napanee 

Water heater load 
Norwood 

Water heater load 
Oshawa 

Water heater load 



$ c. 
64.00 
60.00 
55.00 
105.00 
35.00 



60.00 
37.50 



42.50 



31.50 
37.50 



35.00 



44.50 
37.50 



39.79 
54.00 



67.00 



55.00 
47.00 
42.50 
46.00 

50.00 
97.00 
42.00 



49.00 
49.00 



55.00 
75.00 
37.00 



41.00 
38.00 



$ c. 
66.00 
54.00 
63.00 
95.00 
38.00 



61.00 
41.50 



46.00 



34.00 
40.00 



37.00 



44.00 
41.00 



39.79 
54.50 



65.00 



55.00 
55.00 
42.50 
53.50 

50.00 
97.00 
44.00 



50.00 
53.00 



57.00 
62 00 
40.00 



41.00 
41.00 



$ c 
93,249.45 
11,365.56 
32,937.95 
18,097.18 
765,820.34 



28,414.26 
385,299.03 



62,762.52 



425,107 
28,893 



231,514.34 



50,683.16 
323,055.45 



24,666.09 
46,614.35 



17,875.38 



24,415.41 
52,952.26 
71,820.88 
67.457.30 



22,474.12 

28,963.67 

424,938.79 



42,060.23 
26,033.84 



6,345.15 

34,294.09 

223,511.72 



24,355.74 
2,073,605.71 



194.0 


29.6 


83.7 


26.9 


3,459.5 


20.0 


69.4 


1,513.7 


7.2 


242.7 


0.7 


2,232.0 


131.6 


1.5 


1,000.7 


8.3 


189.1 


1,325.3 


4.7 


92.2 


120.2 


0.5 


40.4 


0.1 


66.9 


143.4 


253.9 


206.2 


67.1 


37.6 


1.590.0 


4.6 


139.3 


83.0 


0.1 


21.3 


76.7 


941.0 


5.1 


93.3 


0.4 


7,946.8 


17.4 



$ c. 
1,551.47 
236.72 
669.37 
215.13 
27,666.63 



555 
12,105 


01 
50 


1,940 


94 


17,849 
1,052 


95 

44 


8,002 


89 


1,512 
10,598 


28 
81 


737 
961 


35 

27 


323 


09 



535.02 
1,146.81 
2,030.51 
1,649.04 

536.62 

300 . 70 

12,715.69 



1,114.02 
663.78 



170.34 
613.39 

7,525.45 



746.15 

63,552.87 



$ 


c. 


3,041 


51 


469 


12 


1,108 


53 


335 


52 


28,857 


24 


*728 


94 


1,106 


30 


15,594 


05 


*296 


57 


2,595 


64 


*29 


29 


15,375 


35 


1,639 


30 


*62 


48 


7,185 


84 


*307 


64 


1,995 


89 


14,511 


15 


*192 


26 


820 


20 


2,102 


92 


*29 


69 


748 


69 


*6 


55 


726 


83 


1,757 


57 


1,955 


67 


2,278 


47 


793 


12 


607 


69 


16,964 


50 


*195 


33 


2,045 


55 


1,221 


81 


*5 


04 


343 


77 


1,344 


75 


8,945 


65 


*199 


17 


1,077 


98 


*17 


16 


72,423 


46 


*704 


08 



$ c. 

4,396.16 

527.49 

1,577.87 

872.62 

36,820.73 



1,360 
18,658 


51 
32 


3,013 


26 


20,086 
1,395 


28, 
94 


10,986 


25 


2,346 
15,594 


13 

73 


1,195 

2,245 


66 

82 


854 


03 



1,178.48 
2,526.85 
3,420.02 
3,231.60 

1,070.03 

1,372.21 

20,400.90 

2,022 .58 

1,248.65 



300.65 

1,610. 49 

10,816.85 

1,164.65 

99,827.38 



*Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



237 



SYSTEM 



E.O.—COST OF POWER 



Power Commission Act — of Power supplied to it by the Commission; the amount 
and the amount remaining to be credited or charged to each Munici- 
of power supplied to it in the year ending October 31, 1933 



costs and fixed charges 


Cost in 
excess of 

revenue 
from power 

sold to 

private 
companies 


Total cost 

of power 

for year as 

provided to 

be paid 

under 

Power 

Commission 

Act 


Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 


Amounts remaining to 
be credited or charged 


Renewals 


Obsoles- 
cence and 
contin- 
gencies 


Sinking 
fund 


to each municipality 
upon ascertainment of 
the actual cost of 
power by annual ad- 
justment 




Credited 


Charged 


$ c. 
1,570.30 

178.81 


$ c. 
292.21 

41.74 
108.34 

52.54 
2,475.94 


$ c. 
960.27 
113.81 
337.19 
187.57 
7,678.34 


$ c. 
877.00 
133.81 
378.38 
121.61 
15,639.13 


$ c 

12,688.92 

1,701.50 

4,712.67 

2,079.02 

126,089. 43 \ 

728.94/ 

4,110.99 

62,349. 97 \ 

296.57/ 

10,153. 79\ 

29 . 29 1 

74,529. 03' 

5,481.46\ 

62.48/ 

37,090.92\ 

307.64/ 

8,143.77 

54,213.74) 

192.26/ 

3,776.33 

7,136.841 

29.69/ 

2,647.42) 
6.55/ 
3,394.89 
7,494.50 
10,608.81 
9,826.37 

3,365.51 

3,358.87 

67,517.57) 

195.33/ 

6,876.00 

4,185.64) 

5.04/ 

1,094.85 

4,940.74 

36,749.09) 

199.17/ 

4,002. 18\ 

17.16/ 

321,561.521 

704.08/ 


$ c. 
12,999.67 
1,656.25 
5,245.41 
2,649.47 
132,971.76 

4,300.89 
63,254.51 

11,234.65 

76,366.95 
5,364.51 

37,782.98 

8,495.78 
54,744.80 

3,748.24 
6,691.54 

2,700.05 

3,747.29 

7,732.17 

11,004.30 

10,962.98 

3,424.93 

3,725.56 

70,937.75 

7,068.35 
4,422.18 

1,223.94 

5,023.64 

38,139.32 

3,916.36 

329,364.17 


$ c. 
310.75 


$ c. 
45 . 25 


532.99 


532.74 

570.45 

6,153.39 

189.90 
607.97 

1,051.57 

1,837.92 




294.03 
6,951.42 




397.77 
4,041.35 


85.91 
1,214.84 


291.76 
3,893.03 


313.73 
6,842.88 




663.03 


211.70 


632.06 


1,097.16 




5,281.94 
387.33 


1,614.86 
121.74 


4,230.60 
289.79 


10,090.05 
594.92 


179.43 




384.42 

352.01 
338.80 




3,199.48 


864.50 


2,328.16 


4,523.80 








736.90 

3,231.43 


184.69 
1,042.19 


513.03 

3,244.24 


854.85 
5,991.19 




272.10 


84.69 
169.45 


249.53 
477.49 


416.80 
543.38 


28.09 


636.51 




474.99 




46.08 

352.40 

237.67 

395.49 

1,136.61 

59.42 
366.69 

3,224.85 

192.35 
231.50 

129.09 

82.90 

1,191.06 




296.97 


58.20 


183.81 


182.63 








324.43 


77.98 
168.40 
255.03 
207.05 

80.55 

86.60 

1,309.31 


249.72 
541.37 
728.44 
685 . 79 

229.50 

300.85 
4,299.08 


302.43 

648.26 

1,147.79 

932.15 

303.34 

169.78 

7,187.81 




705.24 




1,071.35 




842.27 




352.35 




521.04 




4,640.28 








500 . 89 


136.14 
92.96 


427.10 
264.96 


629.72 
375.21 




318.27 








95.55 


23.78 
112.03 
731.72 


64.47 

349.07 

2,260.73 


96.29 

346.73 

4,253.91 




564.28 




2,214.78 








260.48 


84.98 


246.17 


421.77 


102.98. 




7,098.57 




22,345.56 


6,450.31 


21,037.38 


35,924.56 






238 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



EASTERN ONTARIO 

Statement showing the amount to be paid by each Municipality as the Cost — under the 

received by the Commission from each Municipality on account of such cost; 

pality upon ascertainment (by annual adjustment) of the actual cost 



Municipality 



Interim rate 

per 
horsepower 
collected by 
Commission 
during year 



To 

Jan. 1 

1933 



To 

Oct. 31 
1933 



Share of 
capital cost 
of system 
on which 
interest and 
fixed charges 
are payable 



Average 
horse- 
power 

supplied 

in year 

after 

correction 

for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



Ottawa 

Ottawa 

Perth 

Water heater load 
Peterborough 

Water heater load . 
Picton 

Water heater load . 

Port Hope 

Water heater load . 
Prescott 

Water heater load . 

Richmond 

Russell 

Smiths Falls 

W T ater heater load . 



Stirling 

Water heater load 
Trenton 

Water heater load 

Tweed 

Warkworth , 

Wellington , 



Westport 

Whitby 

W' ater heater load 
Williamsburg 

W T ater heater load 
Winchester 

W r ater heater load 



$ c 
24.00 



35.00 
32' 00 
50'00 



41.50 



31.00 



55.00 
65.00 
30.00 



32.00 



28.50 



58.00 
50.00 
46.00 

92.84 
37.00 



43.00 
41.00 



$ c 
26.90 



35.00 
32.66 

50.00 



43.20 



34.00 



55.00 
66.00 
32.00 



34.50 
32.20 



58.00 
57.00 
49.00 

85.00 
40.00 



41.00 
42.00 



Rural Power District 

Alexandria R.P.D. — Hawkesbury E. 

and Lochiel twps 

Arnprior R.P.D. — Fitzroy twp 

Belleville R.P.D.— H unt ingdon, 

Sidney, Thurlow and Tyendinaga 

twps 

Water heater load 
Bowmanville R.P.D. — Darlington 

twp 

Water heater load 
Brighton R.P.D. — Brighton, 

Cramahe and Murray twps 



$ c 
700,975.10 

964.71 
227,089.50 



1,201,849.18 
'266,394.59 



259,812.38 



132,447.79 



19,282.81 

19,603.61 

251,667.22 



44,456.19 



502,048.94 



59,966.70 
20,198.40 
52,293.59 

38,563.79 
243,824.07 



30,088.99 
51,431'. 71 



14,920.99 



66,210.36 

26,816.91 

5,896.11 



5,430.4 

18,883.0 

1,107 

3 

5,781 

48 

772 

6 



1,067.7 

3.1 

746.3 

1.1 

48.8 

44.3 

1,421.3 

11.2 



226.1 

0.5 

2,699.5 

4.3 

147.4 

61.5 

165.2 

61.9 
942.4 

5.3 
155.5 

0.4 
217.7 

0.6 



30.0 



293.9 
0.3 

102.9 
0.2 

22.8 



$ 

48,011 

207,712 

8,855 


c. 
85 
99 
40 


46,238 


73 


6,180 


31 


8,538 


71 


5,968 


38 


390 

354 
11,366 


27 
28 
55 


1,808 


19 


21,588 


68 


1,178 

491 

1,321 

495 
7,536 


80 
83 
15 

03 
65 


1,243 


58 


1,741 


01 


239 
1,692 

2,350 


92 

24 

40 


822 


92 


182 


34 



$ c 

29,891.82 

145.69 

7,227.15 

♦130.48 

37,170.97 

*1,604.76 

7,551.22 

♦330.03 

12,322.92 

*128.48 

5,668.54 

♦36.37 

729.08 

752.42 

9,066.70 

*356.85 

1,706.36 

♦16.81 

15,473.23 

♦133.24 

2,922.67 

941.84 

1,794.05 

1,005.75 

8,320.28 

♦211.55 

1,477.64 

♦14.48 
2,145.57 

♦24.05 



436.60 



2,375.19 
♦10.97 

1,106.08 

♦8.42 

222.21 



$ c. 

33,941.03 

46.49 

10,822.48 



57,681.53 
12,785 .14 



12,500.31 



6,269.30 



928.64 

930.39 

11,911.17 



2.143.56 



24,349.05 



2,889.25 

966.96 

2,512.74 

1,859.91 
11,720.54 



1,423.98 
2,427 '33 



716.07 



3,174.12 



1,291.61 
282.68 



♦Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



239 



SYSTEM 



E.O.—COST OF POWER 



Power Commission Act — of Power supplied to it by the Commission; the amount 
and the amount remaining to be credited or charged to each Munici- 
of power supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Obsoles- 
cence and 
contin- 
gencies 



Sinking 
fund 



Cost in 
excess of 

revenue 
from power 

sold to 

private 
companies 



Total cost 

of power 

for year as 

provided to 

be paid 

under 

Power 

Commission 

Act 



Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 



Amounts remaining to 
be credited or charged 
to each municipality 
upon ascertainment of 
the actual cost of 
power by annual ad- 
justment 



Credited 



Charged 



$ c 

6,203.16 

18.73 

2,968.15 



10,085.92 
'3,440.16 



2,609.46 



1,569.48 



312.57 

325.40 

3,019.74 



344.05 



3,543.21 



836.12 
252.83 
643.54 

676.87 
2,596.91 



368.89 
712.17 



252.78 



614.23 

287.21 

62.27 



$ c. 

2,969.88 

4.75 

873.66 



3,565.53 
"792.78 



836.69 



518.26 



61.79 

63.80 

1,000.98 



134.20 



1,503.46 



178.41 

65.05 

163.39 

127.28 
715.57 



119.36 

198.51 



47.70 



216.15 

85.73 
19.89 



$ c 

6,784.69 

10.16 

2,269.89 



12,017.19 
2.720 ! 77 



2,616.96 



1,310.02 



197.68 
-201.58 
2,494.28 



443.14 



4,988.56 



615.17 
205.29 
532.92 

399.29 
2,466.35 



294.38 
517'. 78 



153.77 



664.71 

271.22 

59.38 



$ c. 
24,548.87 



5,005.70 
26,137.39 
"3,493.54 



4,826.68 



3,373.75 



220.61 

200.26 

6,425.17 



1,022.11 
12', 203 .45 



666.34 
278.02 
746.81 

279.83 
4,260.24 



702.96 
984.14 



135.62 



1,328.61 
465.17 



103.07 



$ 


c. 


152,351 


.30 


207,938 


.81 


38,022 


.431 


130 


48 ( 


192,897 


261 


1,604 


76/ 


36,963 


921 


330 


03/ 


44,251 


731 


128 


481 


24,677 


731 


36 


37 f 


2,840 


64 


2,828 


13 


45,284 


591 


356 


85/ 


7,601 


611 


16 


81 f 


83,649 


641 


133 


24 ( 


9,286 


76 


3,201 


82 


7,714 


60 


4,843 


96 


37,616.54\ 


211 


55 ( 


5,630 


791 


14 


48 f 


8,726. 51\ 
24.05/ 


1,982 


46 


1,692 


24 


10,723 


411 


10.97/ 


4,329.94\ 


8 


.42/ 


931 


.84 



$ c. 

150,880.41 

207,938.81 

39,688.78 

190,754.26 

39,785.88 

46,816.98 

25,501.08 

2,736.72 

2,967.67 

46,235.50 

7,874.16 

87,158.85 

8,719.10 
3,489.94 
8,157.14 

5,449.65 
38,191.19 

6,550.80 

9,306.51 



1,982.46 
1,692.24 



10,734.38 

4,338.36 

931.84 



$ ' c. 



1,535.87 



2,491.93 

2,436.77 
786.98 



139.54 
594.06 



255.74 
3.375.97 



288.12 
442.54 

605.69 
363 . 10 

905.53 

555.95 



see page 



$ c. 
,470.89 



3,747.76 



103.92 



567.66 



247 



240 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



EASTERN ONTARIO 

Statement showing the amount to be paid by each Municipality as the Cost — under the 

received by the Commission from each Municipality on account of such cost; 

pality upon ascertainment (by annual adjustment) of the actual cost 



Rural power district 



Share of 

capital cost 

of system 

on which 

interest and 

fixed charges 

are payable 



Average 
horse- 
power 

supplied 

in year 

after 

correction 

for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 


Operating, 




main- 




tenance 


Interest 


and 


(including 


adminis- 


exchange) 


trative 




expenses 





Brockville R.P.D. — Augusta, Eliza- 
bethtown, Escott Front, Leeds and 
Lansdowne Front, Leeds and Lans- 
downe Rear, Yonge Front and 

Yonge and Escott Rear twps 

Water heater load 

Campbellford R.P.D. — Rawdonand 
Seymour twps 

Carleton Place R.P.D.— Ramsay 
twp 

Chesterville R.P.D. — Cambridge, 
Finch, Osnabruck, Russell, Wil- 
liamsburg and Winchester twps.. . . 

Cobourg R.P.D.— Alnwick, Haldi- 

mand, Hamilton and Hope twps. . . 

Water heater load 

Colborne R.P.D. — Cramahe and 
Haldimand twps 

Fenelon Falls R.P.D.— B e x 1 e y, 
Fenelon, Laxton, Digby, Longford 

and Somerville twps 

Water heater load 

Iroquois R.P.D. — Gower S., Matilda 
Mountain, Oxford, W'illiamsburg 

and Winchester twps 

Water heater load 

Kemptville R.P.D.— Oxford twp. . . 

Kingston R.P.D.— Bedford, Ernes- 
town, Hinchinbrooke, Kingston, 
Leedsand LansdowneFront, Lough- 
brough, Oso, Pittsburgh and Port- 
land twps 

Water heater load 

Lakefield R.P.D.— B urleigh and 
Anstruther, Douro, Harvey and 
Smith twps 

Lindsay R.P.D. — Fenelon, Ops and 
Verulam twps 

Martintown R.P.D. — Charlotten- 

burg and Lancaster twps 

Water heater load 

Maxville R.P.D. — Caledonia, Ken- 
yon, Plantagenet N., Plantagenet 
S. and Roxborough twps 

Millbrook R.P.D. — Cavan, Manvers 
and Monoghan S. Twps 

*Heater costs written off in year 



$ c. 



60,280.04 



12,150.02 



57,288.75 
58,271.79 



30,551.99 
12.745.30 



54,160.94 
'5,595.83 

73,596.57 



8,922.41 

5,327.15 

14,718.34 



60,233.29 
12.329.22 



266.4 
0.1 

58.4 



179.1 

229.5 
0.5 



109.3 



39.1 
0.2 



360.4 

0.1 

18.6 



270.5 
0.2 



30.2 

17.5 

46.2 
0.1 

140.9 
36.9 



2,130.48 



467.04 
26.54 

1,432.32 
1,835.37 



874.10 



312.69 



2,882.22 



148.75 



3.172.52 



241.52 
139.96 
369.47 



1,126.82 
295.10 



2,297.97 

*3.84 

347.21 



1,630.24 

2,369.80 
*20.49 



975.43 



493 . 73 
*9.87 



2,048.18 

*2.91 

263.77 



2,501.47 
*9.19 



269.84 

198.85 

445 . 22 
*4.65 

1,844.23 
479.47 



2,865.63 



579.24 



2,736.98 
2,782.22 



1,468.72 



614.14 



2,607.30 



269.59 



3,523.61 



429.94 
256.94 
691.58 



2,851.53 
586.42 



to extent of revenue available from heater loads. 



1934 



HYDRO- ELECTRIC POWER COMMISSION 



241 



SYSTEM 



E.G.— COST OF POWER 



Power Commission Act— of Power supplied to it by the Commission; the amount 
and the amount remaining to be credited or charged to each Munici- 
of power supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Obsoles- 
cence and 
contin- 
gencies 



Sinking 
fund 



Cost in 
excess of 

revenue 
from power 

sold to 

private 
companies 



Total cost 

of power 

for year as 

provided to 

be paid 

under 

Power 

Commission 

Act 



Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 



Amounts remaining to 
be credited or charged 
to each municipality 
upon ascertainment of 
the actual cost of 
power by annual ad- 
justment 



Credited 



Charged 



818.85 



102.12 



882.20 
609.04 



346.31 
160.09 



566.84 



85.15 



812.37 



105.36 

64.12 

228.31 



982.94 
154.00 



225.68 



39.04 



202.80 
192.79 



106.78 
43.19 



211.85 



20.36 



236.10 



27.24 
17.66 
54.36 



204.51 
42.28 



605 . 13 



121.49 



583.68 
588.10 



309.62 
129.89 



530.72 



56.89 



743.59 



90.62 

54.17 

150.90 



611.24 
124.38 



1,204.30 



264.01 



809 . 65 
1,037.49 



494.11 

176.76 



1,629.24 



84.08 



1,222.83 



136.52 
"79.11 
208.85 



636.95 
166.81 



10,148. 04\ 

3.84/ 

1,920.15 
26.54 

8,277.87 

9,414.811 
20.49/ 

4,575.07 



1,930.49 
9.87 



10,476.35) 
2.91/ 
928.59 



12,212. 49\ 
9 . 19/ 



1,301.04 

810.81 

2,148.69 
4.65 

8,258.22 
1,848.46 



$ 


c. 


10,151 


88 


1,920 


15 


26 


54 


8,277 


87 


9,435 


30 


4,575 


07 


1,940 


36 


10,479 


26 


928 


59 


12,221 


68 


1,301 


04 


810 


81 


2,153 


34 


8,258 


.22 


1,848 


.46 



see page 



247 



242 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



EASTERN ONTARIO 

Statement showing the amount to be paid by each Municipality as the Cost — under the 

received by the Commission from each Municipality on account of such cost; 

pality upon ascertainment (by annual adjustment) of the actual cost 



Rural power district 



Share of 

capital cost 

of system 

on which 

interest and 

fixed charges 

are payable 



Average 
horse- 
power 

supplied 

in year 

after 

correction 

for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 


Operating, 




main- 




tenance 


Interest 


and 


(including 


adminis- 


exchange) 


trative 




expenses 





Napanee R. P. D . — Camden E. , Ernes- 
town, Fredericksburg S., Fredericks- 
burg N., Hungerford, Portland, 
Richmond, Sheffield and Tyen- 
dinaga twps 

Nepean R.P.D. — Clarence, Cumber- 
land, Gloucester, Goulburn, Gower 
N., March, Nepean and Osgoode 
twps 

Newcastle R.P.D. — Clarke, Darling- 
ton and Manvers twps 

Water heater load 

Norwood R.P.D.— Asphodel, Bel- 
mont and Methuen, Dummer and 
Seymour twps 

Omemee R.P.D. — Emily and Ops 
twps 



Oshawa R.P.D. — Darlington, Picker- 
ing, Uxbridge, Whitby and Whitby 

E. twps 

Water heater load 

Perth R.P.D.— Bathurst, Burgess N., 
Elmsley N., and Elmsley S. twps.. . 

Peterborough R.P.D. — Cavan, 
Douro, Monoghan N., Monoghan 

S., Otonabee and Smith twps 

Water heater load 

Prescott R. P. D. — Augusta, Edwards- 
burg and Matilda twps 

Water heater load 

Renfrew R.P.D. — Admaston and 
Horton twps 



Smiths Falls R.P.D.— Bastard and 
Burgess S., Crosby S., Kitley, Mon- 
tague and Wolford twps 

Water heater load 

Stirling R.P.D.— Rawdon and Sid- 
ney twps 

Trenton R.P.D. — Brighton, Murray 
and Sidney twps 

Warkworth R.P.D. — Percy twp. . . . 

Wellington R.P.D. — Ameliasburg, 
Athol, Hallowell, Hillier and Mur- 
ray twps 

Water heater load 



$ c. 

56,741.54 

84,487 . 05 
18.378.25 



15,688.36 
806.47 

156,471.60 



6,395.65 
94,027.87 
19,194.09 



38,131.44 



9,130.3: 

34,461.26 
738.44 



52,802.53 



197.8 



563.4 

60.6 
0.3 



45.1 

2.4 



593.1 
1.1 

29.8 



427.9 
0.8 

99.4 
0.1 



145.2 
0.1 

42.7 

170.7 
3.0 



163.0 
0.4 



1,581.87 

4,505.67 
484.64 



360.67 
19.19 

4.743 . 19 



268.56 
3.422.04 



988.34 
612.16 

1.161.20 



341.48 

1,365.14 
23.99 



1,303.57 



$ 


c. 


1,700 


28 


3,311 


37 


815 


14 


*o 


65 


486 


45 


23 


31 


6,468.67 
*46.47 


350 


97 


3,408.95 
*28.67 


983 


65 


*3 


85 


1,008 


56 


*4 


17 


414 


85 


1,536 
39 


13 
17 


1,767 

*18 


56 
33 



2,728.10 

4,047.12 
880.57 

755.75 
38.60 

7,512.78 
308.97 

4,493.58 
894.28 



1.825.04 



436.62 

1,663.51 

35.22 



2,535.51 



"Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



243 



SYSTEM 



E.O.—COST OF POWER 



Power Commission Act — of Power supplied to it by the Commission; the amount 
and the amount remaining to be credited or charged to each Munici- 
of power supplied to it in the year ending October 31, 1933 



costs and fixed charges 


Cost in 
excess of 

revenue 
from power 

sold to 

private 
companies 


Total cost 

of power 

for year as 

provided to 

be paid 

under 

Power 

Commission 

Act 


Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 


Amounts remaining to 
be credited or charged 


Renewals 


Obsoles- 
cence and 
contin- 
gencies 


Sinking 
fund 


to each municipality 
upon ascertainment of 
the actual cost of 
power by annual ad- 
justment 




Credited 


Charged 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$' c. 


$ c. 


655.34 


187.54 


576.26 


894.18 


8,323.57 


8,323.57 


see page 


249 


877.26 


363.62 


827.76 


2,546.92 


16,479.72 


16,479.72 


- 


a 


219.93 


62.48 


186.69 


273.95 


2,923. 40\ 
9.65/ 

2,223.34 


2,933.05 


a 


a 


204.60 


51.87 


160.12 


203.88 


2,223.34 


u 


« 


10.22 


2.83 


8.22 


10.85 


113.22 


113.22 


a 


" 


1,699.15 


480.49 


1,587.01 


2,681.18 


25,172.47) 
46.47/ 


25,218.94 


u 


a 


85.64 


24.96 


64.08 


134.71 


1,237.89 


1,237.89 


« 


a 


846.81 


289.24 


942.88 


1,934.58 


15,338. 08\ 
28.67/ 


15,366.75 


u 


« 


239.69 


76.79 


190.84 


449.35 


3,822. 94\ 

3.85/ 

612.16 


3,826.79 


ii 


u 










612.16 


u 


u 


552.73 


158.30 


385.62 


656.39 


5,747.84) 

4.17/ 


5,752.01 


u 


u 


79.51 


29.02 


91.42 


193.03 


1,585.93 


1,585.93 


a 


a 


278.05 
7.46 


108.84 

2.57 


344.03 

7.42 


771.67 
13.56 


6,067.37 
129.39 


6,067.37 
129.39 


« 


u 


660.33 


171.05 


538.88 


736.86 


7,713.76) 
18.33/ 


7,732.09 


u 


u 













244 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



EASTERN ONTARIO 

Statement showing the amount to be paid by each Municipality as the Cost — under the 

received by the Commission from each Municipality on account of such cost; 

pality upon ascertainment (by annual adjustment) of the actual cost 



Rural power district 



Share of 

capital cost 

of system 

on which 

interest and 

fixed charges 

are payable 



Average 
horse- 
power 
supplied 
in year 
after 
correction 
for power 
factor 



Cost of 
power 
pur- 
chased 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



Williamsburg R. P. D.— Matilda and 

Williamsburg twps 

Water heater load 



Totals — Municipalities 

Water heater loads 
Totals — Rural Power Districts 

Water heater loads 

Totals — Companies 

Totals — Local Electric distribution 
systems 

Water heater loads 
Totals — Local Gas distribution sys- 
tem 

Totals— Pulp Mill 



Non-operating capital . 
Campbellford Pulp Mil 

Grand totals 



$ c. 
9.520.11 





9,792,544 


22 


1,176,990.98 


5,385,552 
136,805 


10 

37 


26,534 
276,232 


67 

42 



16,794,659.76 

2,526.11 

52,559.93 



16,849,745.80 



51.9 
0.4 



62,398.4 

155.9 

4,848.6 

4.9 

20,117.1 

258.7 
0.5 



1,425.5 



89,209.6 



$ c. 
473.22 



560,301.63 
"42. 397 .65 



160,882.29 
2,068.91 



11,400.14 



777,050.62 



441.01 
*14.45 



356,287.97 

♦5,761.30 

43,061.56 

♦195.93 

201,482.46 

8,677.68 
♦20.80 

16,632.61 
8,270.42 



640,390.73 



$ c. 
463 . 26 



470 232.94 
' 56.347 .23 



269,208.31 
6,601.23 



1.278.56 
13,420.94 



817,089.21 



♦Heater costs written off in year to extent of revenue available from heater loads. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



245 



SYSTEM 



E.O.—COST OF POWER 



Power Commission Act — of Power supplied to it by the Commission; the amount 
and the amount remaining to be credited or charged to each Munici- 
of power supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Obsoles- 
cence and 
contin- 
gencies 



Sinking 
fund 



Cost in 
excess of 

revenue 
from power 

sold to 

private 
companies 



Total cost 

of power 

for year as 

provided to 

be paid 

under 

Power 

Commission 

Act 



Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 



Amounts remaining to 
be credited or charged 
to each municipality 
upon ascertainment of 
the actual cost of 
power by annual ad- 
justment 



Credited 



Charged 



$ c 
121.8/ 



$ c. 
39.09 



$ c. 
95.92 



$ c. 
222.42 



1,856.79\ 
14.45/ 



$ c. 

1,871.24 



$ c. 
see page 



$ c. 
249 



103,956.49 



32,333.73 



98,381.41 



196,716.94 



13,672.78 

43,170.61 

1,975.79 



4,042.80 

14,228.82 

268.95 



11,856.65 

42,322.28 

854.98 



21,906.71 
(218,6?3.65) 



2,091.44 



851.33 



2,751.09 



1,818,211.11\ 

5,761.30/ 

193,285.38\ 

195.93/ 

512,671.12 

20,447.541 
20.80/ 

17,911.17 
38,785.36 



1,859,103.83 

193,481.31 

512,671.12 

23,922.25 



15,738.90 
38,785.36 



41,852.39 



6,720.97 



3,453.91 



2,172.27f 



164,867.11 51,725.63 



56,166.41 2,607,289.71 2,643,702.77 

I 



fSurplus of $1,281.64 transferred to credit of obsolescence and contingencies reserve. 



246 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



EASTERN ONTARIO SYSTEM— 

Statement showing the costs of distribution of power within each Rural Power 
and the amounts remaining to be credited to certain Districts or charged 

(by annual adjustment) of the actual costs 



District and municipalities 
comprised therein 



Total capital cost of each district, 
Provincial Government grant 
received and applied thereagainst, 
and the balance representing the 
investment by the Commission 



Total 

capital 

cost 



Govern- 
ment 
grant 



Com- 
mission's 
investment 



Cost of 

power 

delivered 

to districts 

as shown 

in "cost of 

power" 

table 

preceding 



Alexandria R.P.D. — Hawkesbury E. and 
Lochiel twps 

Arnprior R.P.D. — Fitzroy twp 

Belleville R.P.D. — Huntingdon, Sidney, 
Thurlow and Tyendinaga twps 

Bowmanville R.P.D. — Darlington twp 

Brighton R.P.D. — Brighton, Cramahe and 
Murray twps 



Brockville R.P.D. — Augusta, Elizabethtown, 
Escott Front, Leeds & Lansdowne Front, 
Leeds & Lansdowne Rear, Yonge Front 
and Yonge & Escott Rear twps 

Campbellford R.P.D. — Rawdon and Sey- 
mour twps 

Carleton Place R.P.D. — Ramsay twp 

Chesterville R.P.D.— Cambridge, Finch, Os- 
nabruck, Russell, Williamsburg and Win- 
chester twps 

Cobourg R.P.D. — Alnwick, Haldimand, 
Hamilton and Hope twps 



Colborne R.P.D. — Cramahe and Haldimand 



twps 

Fenelon Falls R.P.D. — Bexley, Fenelon, 
Laxton, Digby, Longford and Somerville 
twps 

Iroquois R.P.D. — Gower S., Matilda, Moun- 
tain, Oxford, Williamsburg and Winchester 
twps 

Kemptville R.P.D.— Oxford twp 

Kingston R.P.D. — Bedford, Ernestown, 
Hinchinbrooke, Kingston, Leeds & Lans- 
downe Front, Loughborough, Oso, Pitts- 
burgh and Portland twps 



Lakefield R.P.D.— Burleigh and Anstruther, 
Douro, Harvey and Smith twps 

Lindsay R.P.D. — Fenelon, Ops and Verulam 
twps 

Martintown R.P.D. — Charlottenburg and 
Lancaster twps 

Maxville R.P.D. — Caledonia, Kenyon, Plan- 
tagenet N., Plantagenet S. and Roxborough 
twps 

Millbrook R.P.D. — Cavan, Manvers and 
Monoghan S. twps 



$ 


c. 


27,482 
12,715 


78 
46 


148,173 
41,124 


49 

53 


14,613 


69 


♦221,292 


88 


34,908 
896 


83 
67 


*95,010 


97 


182,240.98 


50,124 


15 


40,835 


33 


174,264 
11,335 


61 
47 


262,539 


82 


*47,105 


86 


37,461 


48 


49,189 


50 


118,216 


38 


29,504 


34 



13,741.39 
6,114.10 

73,407.78 
20,562.27 

7,306.85 



108,076.28 

17,454.41 
448.34 



45,984.45 
90,384.28 

25,062.08 

19,993.49 



86,788.95 
5,520.91 



127,237.90 

23,442.25 
18,730.74 
24,594.75 

59,108.19 
14,468.27 



$ 


c. 


13,741 
6,601 


39 
36 


74,765 
20,562 


71 
26 


7,306 


84 


13,216 


60 


17,454 
448 


42 
33 


49,026 


52 


91,856 


70 


25,062 


07 


20,841 


84 


87,475 
5,814 


66 
56 


35,301 


92 


23,663 


61 


18,730 


74 


24,594 


75 


59,108 


19 


15,036.07 



1,982.46 
1,692.24 

10,734.38 
4,338.36 

931.84 



10,151.88 

1,920.15 
26.54 



8,277.87 
9,435.30 

4,575.07 

1,940.36 



10,479.26 
928.59 



12,221.68 

1,301.04 

810.81 

2,153.34 

8,258.22 
1,848.46 



Note. — Items marked * include portions 
for purposes of rural power districts. 



of transmission lines aggregating $22,387.41 used 



934 



HYDRO- ELECTRIC POWER COMMISSION 



247 



RURAL POWER DISTRICTS 



E.O.— RURAL OPERATING 



District, the revenues collected from (or charged to) customers within each District, 
to the Municipalities comprising certain other Districts upon ascertainment 
in the year ending October 31, 1933 



Distribution costs and fixed charges 



Cost of 
operation 
mainten- 
ance and 
adminis- 
tration 



Interest 
(including 
exchange) 



Renewal 
charges 



Obsoles- 
cence and 
contin- 
gencies 



Sinking 
fund 



Total 
cost 



Revenue 

from power 

and light 

customers 

in each 

district 



Amounts remaining 
to be credited to 
certain districts or 
charged to the 
municipalities com- 
prising certain other 
districts 



Credited Charged 



$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


% c. 


$ c. 


$ c. 


$ c. 


899 . 69 
509.84 


654 12 
315.19 

3,524.08 
989.54 


543.01 
252.51 

2,898.32 
821.46 


271.51 
126.25 

1,449.16 
410.73 


142.95 
69.04 

770.13 
216.25 


4,493.74 
2,965.07 

24,760.90 
7,972.64 


3,816.93 
2,606.54 

27,043.18 
7,681.75 




676.81 

358.53 


5,384.83 
1,196.30 


2,282.28 


"290.89 


534.86 


351.51 


291.80 


145.90 


76.82 


2,332.73 


2,712.70 


379.97 




10,341.41 


5,341.93 


4,332.92 


2,166.47 


1,167.39 


33,502.00 


32,240.06 




1,261.94 


2,174.41 
5.16 


833.60 

21.47 


692.00 
17.84 


346.00 
8.92 


182.17 
4.70 


6,148.33 
84.63 


4,394.17 
67.21 




1,754.16 
17.42 


4,449 . 79 


2,347.39 


1,887.82 


943.90 


512.99 


18,419.76 


16,357.88 




2,061.88 


5,062.36 


4,371.32 


3,599.36 


1,799.68 


955.28 


25,223.30 


23,864.99 




1,358.31 


2,734.24 


1,184.44 


983 . 25 


491.63 


258.84 


10,227 .47 


8,342.93 




1,884.54 


805.56 


986.16 


801.70 


400.85 


215.51 


5,150.14 


4,853.28 




296.86 


6,179.59 
211.70 


4,178.61 
279.31 


3,456.19 
226.00 


1,728.10 
112.99 


913.17 
61.04 


26,934.92 
1,819.63 


27,210.78 
1,926.13 


275.86 
106.50 




12,923.01 


6,214.94 


4,998.53 


2,499.27 


1,358.18 


40,215.61 


33,561.31 




6,654.30 


633.66 


1,077.03 


889.66 


444.82 


235.37 


4,581.58 


3,547.41 




1,034.17 


897.67 


662.64 
1,175.30 


550.08 
975.66 


275.04 
487.83 


144.81 
256.84 


3,341.05 
6,958.85 


2,428.62 
6,600.96 




912.43 


1,909.88 




357.89 


3,452.79 


2,802.65 


2,326.60 


1,163.28 


612.48 


18,616.02 


17,829.98 




786.04 


1,009.90 


718.94 


585.47 


292.73 


157.11 


4,612.61 


4,329.71 




282.90 



248 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



EASTERN ONTARIO SYSTEM— 

Statement showing the costs of distribution of power within each Rural Power 
and the amounts remaining to be credited to certain Districts or charged 

(by annual adjustment) of the actual costs 



District and municipalities 
comprised therein 



Total capital cost of each district, 
Provincial Government grant 
received and applied thereagainst, 
and the balance representing the 
investment by the Commission 



Total 

capital 

cost 



Govern- 
ment 
grant 



Com- 
mission's 
investment 



Cost of 

power 

delivered 

to districts 

as shown 

in "cost of 

power" 

table 

preceding 



Napanee R.P.D. — Camden E., Ernestown, 

Fredericksburg S., Fredericksburg N., 
Hungerford, Portland, Richmond, Sheffield 
and Tyendinaga twps 

Nepean R.P.D. — Clarence, Cumberland, 
Gloucester, Goulburn, Gower N., March, 
Xepean and Osgoode twps 

Newcastle R.P.D. — Clark, Darlington and 
Manvers twps 

Norwood R.P.D. — Asphodel, Belmont and 
Methuen, Dummer and Seymour twps. . . . 

Omemee R.P.D. — Emily and Ops twps 



Oshawa R.P.D. — Darlington, Pickering, 
Uxbridge, Whitby and Whitby E. twps. . . 

Perth R.P.D.— Bathurst, Burgess N., Elms- 
ley N. and Elmsley S. twps 

Peterborough R.P.D. — Cavan, Douro, Mon- 
oghan N., Monoghan S., Otonabee and 
Smith twps 

Prescott R.P.D. — Augusta, Edwardsburg 
and Matilda twps 

Renfrew R.P.D. — Admaston and Horton 
twps 



Smiths Falls R.P.D.— Bastard & Burgess S., 
Crosby S., Kitley, Montague and Wolford 
twps 

Stirling R.P.D. — Rawdon and Sidney twps. . 

Trenton R.P.D. — Brighton, Murray and 
Sidney twps 

Warkworth R.P.D. — Percy twp 

Wellington R.P.D.— Ameliasburg, Athol, 
Hallowell, Hillier and Murray twps 



Williamsburg R.P.D. 

Williamsburg twps 



Matilda and 



Non-operating capital 
Totals 



: 207, 552. 83 



=334,380 

*38,203 

*18,925 
3,613 

279,858 
28,981 

177,366 

75,844 

7,887 



117,659 
*51,177 

*74,143 
*1.671 



165,086.64 



35,451.63 



3,216,840. 
9,465 



3,226,305.45 



100,977.94 

162,727.79 

18,170.90 

9,124.47 
1,806.55 

136,402.87 
14,490.61 

88,683.13 

37,741.12 

3,943.59 



56,935.36 
23,212.00 

36,978.41 
648.75 

82,029.95 



17.725.81 



1,580,026.93 
4,732.72 



1,584,759.65 



106,574.89 

171,653.18 

20,032.30 

9,800.61 
1,806.55 

143,455.35 
14,490.62 

88,683 . 13 

38,103.31 

3,943.60 



60,724.53 
27,965.49 

37,165.19 
1,022.29 

83,056.69 



17,725.82 



,636,813.09 
4,732.71 



,641,545.80 



8,323.57 

16,479.72 

2,933.05 

2,223.34 
113.22 

25,218.94 
1,237.89 

15,366.75 

3,826.79 

612.16 



5,752.01 
1,585.93 

6,067.37 
129.39 

7,732.09 



1,871.24 



193,481.31 



Note. — Items marked * include portions of transmission lines aggregating $22,387.41 used 
for purposes of rural power districts. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



249 



RURAL POWER DISTRICTS 



E.O.—R URA L OPERA TING 



District, the revenues collected from (or charged to) customers within each District, 
to the Municipalities comprising certain other Districts upon ascertainment 
in the year ending October 31, 1933 



Distribution costs and fixed charges 



Cost of 
operation 
mainten- 
ance and 
adminis- 
tration 



Interest 
(including 
exchange) 



Renewal 
charges 



Obsoles- 
cence and 
contin- 
gencies 



Sinking 
fund 



Total 
cost 



Revenue 

from power 

and light 

customers 

in each 

district 



Amounts remaining 
to be credited to 
certain districts or 
charged to the 
municipalities com- 
prising certain other 
districts 



Credited 



Charged 



5,429.16 

13,796.88 

1,544.04 

693.28 
60.86 

11,934.00 
859.00 

6,210.32 

3,482.84 

129.68 

5,899.20 
880.63 

2,231.81 
102.74 

5,132.78 
1,508.97 



5,070.74 

8,163.24 
964.10 

467.27 

87.05 

6,655.94 
680.70 

4,200.49 

1,815.57 

189.20 

2,908.06 
1,330.66 

1,786.54 
47.80 

3,979.96 
786.97 



4,097.75 

6,598.33 

763.09 

374.40 
72.26 

5,384.32 
565.08 

3,487.00 

1,499.93 

157.48 



2,338.31 
1,009.58 

1,479.37 
32.21 

3,283.39 



653.30 



2,048.89 

3,299.16 

381.56 

187.20 
36.13 

2,692.17 

282.54 

1,743.50 
749.96 

78.74 



1,169.16 
504.79 

739.67 
16.11 

1,641.70 



326.65 



1,108.13 

1,783.95 

210.69 

102.11 
19.02 

1,454.55 
148.76 

917.95 

396.77 

41.46 



635.51 
290.80 

390.42 
10.44 

869.76 



171.98 



26,078.24 

50,121.28 

6,796.53 

4,047.60 
388.54 

53,339.92 
3,773.97 

31,926.01 

11,771.86 

1,208.72 



18,702.25 
5,602.39 

12,695.18 
338.69 

22,639.68 



5,319.11 



21,821.88 

46,715.75 

6,039.36 

3,298.91 
136.63 

55,689.52 
2,324.57 

31,146.33 

10,976.47 

900.53 



16.949.30 
4,993.37 

12,405.77 
294.71 

19,882.59 



5,236.52 



2,349.60 



4,256.36 

3,405.53 

757.17 

748.69 
251.91 



1,449.40 

779.68 
795.39 
308.19 

1,752.95 
609.02 

289.41 
43.98 

2,757.09 
82.59 



121,212.84 



77,164.46 



62,925.98 



31,462.99 



16,863.37 



503,110.95 



470,228.73 



5,394.21 



38,276.43 



250 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



EASTERN ONTARIO 

Statement showing the net Credit or Charge to each Municipality in respect of power 

made and interest added during the year. Also the net amount Credited 

ending October 31, 1933, and the accumulated amount standing 



Municipality 



Date 

commenced 

operating 



Net credit or charge at 
October 31, 1932 



Credit Charge 



Cash receipts and 
payments on account 
of such credits and 
charges, also adjust- 
ments made during 
the year 



Credited Charged 



Alexandria . . . 
Apple Hill . . . 

Athens 

Bath 

Belleville 

Bloomfield . . . 
Bowmanville . 

Brighton 

Brockville. 
Cardinal 

Carleton Place 
Chesterville . . . 

Cobourg 

Colborne 

Deseronto. 

Finch 

Hastings 

Havelock 

Kemptville. . . . 
Lakefield 

Lanark 

Lancaster 

Lindsay 

Madoc 

Marmora 

Martintown . . . 

Maxville 

Napanee 

Norwood 

Oshawa 

Ottawa 

Perth 

Peterborough . . 

Picton 

Port Hope 

Prescott 

Richmond . . . . 

Russell 

Smiths Falls. . . 
Stirling 

Trenton 

Tweed 

Warkworth. . . . 
Wellington 
West port 



Jan., 


1921 


April, 


1921 


Jan., 


1929 


Nov., 


1931 


April, 


1929 


April, 


1919 


Oct., 


1931 


Nov., 


1929 


April, 


1915 


July, 


1930 


May, 


1919 


April, 


1914 


Jan., 


1932 


Jan., 


1933 


Jan., 


1931 


Feb., 


1928 


June, 


1931 


Feb., 


1921 


Dec, 


1921 


Aug., 


1920 


Sept., 


1921 


May, 


1921 


Mar., 


1928 


Jan., 


1930 


Jan., 


1921 


May, 


1921 


Feb., 


1921 


Nov., 


1929 


Feb., 


1921 


Feb., 


1929 


Jan., 


1914 


Feb., 


1919 


Mar., 


1913 


April, 


1919 


Nov., 


1929 


Dec, 


1913 


Aug., 


1928 


Feb., 


1926 


Sept., 


1918 


Jan., 


1930 


Sept., 


1931 


Dec, 


1930 


Oct., 


1923 


April, 
Nov.. 


1919 
1931 



$ c 
694.85 
242.96 
64.05 
366.47 
5,694.08 

415.50 



221.82 

5,456.06 

314.23 

3,880.22 
1,140.89 
2,273.76 



848.06 

338.15 
447.41 



797.30 



395.44 



636.74 
145.56 

73.66 
1,580.72 
2,294.36 

48.52 



3,572.73 

13,122.41 

4,492.82 

75.75 

431.43 
263.69 
293.08 
4,436.46 
323.51 

2,427.34 



454.82 
815.25 



1,824.91 



348.49 



1,065.39 



5,762.49 
3,378.24 



9,505.06 
1,597.54 



993.58 
203.36 



1,824.91 



348.49 



,065.39 



1,062.49 

3,378.24 

6.37 



9,505.06 
1,639.95 



993.58 
203.36 



$ c 
701.85 
242.96 
64.05 
366.47 
5,694.08 

415.50 



221.82 

5,456.06 

314.23 

3,880.22 
1,140.89 
2,273.76 



848.06 

338.15 
447.41 



797.30 



395.44 



643.11 
145.56 

73.66 
1,580.72 
2,294.36 

48.52 



3,572.73 

13,122.41 

4,492.82 

75.75 

431.43 
263.69 
293.08 
4,436.46 
323.51 

2.427.34 



454.82 
815.25 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



25 



SYSTEM 



E.O.— CREDIT OR CHARGE 



supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments 
or Charged to each Municipality in respect of power supplied in the year 
as a Credit or Charge to each municipality at October 31, 1933 



Interest at 4% per annum 
added during the year 


Net amount credited or charged 
in respect of power supplied in 
the year ending October 31, 1933 


Accumulated amount standing 

as a credit or charge on 

October 31, 1933 


Credited 


Charged 


Credited 


Charged 


Credit 


Charge 


$ c. 
10.91 


$ c. 


$ c. 
310.75 


$ c. 


$ c. 
321.66 


$ c. 


3.38 




45.25 


41 87 


1.02 




532.74 

570.45 

6,153.39 

189.90 

607.97 

1,051.57 

1,837.92 


533.76 

575.67 

6,236.38 

195.36 

583.97 

1,054.58 

1,915.74 




5.22 








82.99 








5.46 








24.00 






3.01 






77.82 








4.44 




179.43 


174.99 


78.46. . 




384.42 
352.01 
338.80 


462.88 
369.37 
338.80 




17.36 




















28.09 
474.99 


28 09 


12.28 








462.71 


5.21 




46.08 

352.40 

237.67 

395.49 

1,136.61 

59.42 

366.69 

3,224.85 

192.35 

231.50 

129.09 

82.90 

1,191.06 


51.29 

358.82 

232.13 

406.15 

1,119.80 

65.23 




6.42 










5.54 






10.66. . 








16.81 






5.81 








194.40 
49.98 





4,527.71 






3,174.87 
203.03 
233.91 

130.07 

109.94 

1,221.23 


10.68 






2.41 








0.98 








27.04 








30.17 








0.63 




102.98 


102 35 




133.33 
40.09 


7,098.57 


6,965.24 




1.70 


1,470.89 


1,466.87 


52.47 


1,535.87 


1,588.34 


175.44 




3,747.76 


3,572.32 


67.22 




2,491.93 
2,436.77 

786.98 


2,559.15 
2,437.72 

793.07 


0.95 








6.09 








5.31 




103.92 


98 61 


5.15 




139.54 
594.06 

255.74 

3,375.97 


144.69 
665.53 
260.21 

3,407.89 




71.47 








4.47 








31.92 










22.60 
4.23 


567.66 


590 26 




288.12 
442.54 
605.69 


283.89 
448.67 
617.54 




6.13 






11.85 









252 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



EASTERN ONTARIO 

Statement showing the net Credit or Charge to each Municipality in respect of power 

made and interest added during the year. Also the net amount Credited 

ending October 31, 1933, and the accumulated amount standing 



Municipality 



Date 

commenced 
operating 



Net credit or charge at 
October 31, 1932 



Credit Charge 



Cash receipts and 
payments on account 
of such credits and 
charges, also adjust- 
ments made during 
the year 



Credited Charged 



Whitby 

Williamsburg. 
Winchester. . . 



Rural Power District* 

Alexandria R.P.D 

Arnprior R.P.D 

Belleville R.P.D 

Bowmanville R.P.D 

Brighton R.P.D 



Brockville R.P.D 

Campbellford R.P.D. 
Carleton Place R.P.D. 
Chesterville R.P.D. 
Cobourg R.P.D 



Colborne R.P.D 

Fenelon Falls R.P.D. 

Iroquois R.P.D 

Kemptville R.P.D. . 
Kingston R.P.D 



Lakefield R.P.D.. 

Lindsay R.P.D 

Martintown R.P.D. 

Maxville R.P.D 

Millbrook R.P.D.. . 



Napanee R.P.D.. 
Nepean R.P.D.. . 
Newcastle R.P.D. 
Norwood R.P.D.. 
Omemee R.P.D. 



Oshawa R.P.D 

Perth R.P.D 

Peterborough R.P.D. 

Prescott R.P.D 

Renfrew R.P.D 



Smiths Falls R.P.D. 

Stirling R.P.D 

Trenton R.P.D 

Warkworth R.P.D. 
Wellington R.P.D... 



Williamsburg R.P.D. 

Totals 



Jan., 

April, 

Jan., 


1926 
1915 
1914 


Dec, 


1929 
1930 
1927 
1924 
1929 

1921 
1924 
1932 
1921 
1927 


Dec, 


Aug., 
Jan., 
Nov., 


Nov., 
Aug., 
Feb., 


Nov., 
Feb., 


Aug., 
July, 
July, 
Dec, 
Jan., 


1925 
1931 
1930 
1930 
1923 


July, 
July, 
Jan., 
Dec. 
July, 


1928 
1930 
1922 
1927 
1930 


Nov., 
Feb., 
Sept. 
Jan., 
Jan., 


1927 
1922 
1927 
1929 
1931 


April 
Aug., 
Jan., 
June, 
Nov., 


1918 
1931 
1927 
1922 
1930 


May, 
Nov. 
Jan., 
Nov. 
Nov. 


1929 
1929 
1924 
1928 
1925 


Feb., 


1923 





565.44 
956.53 



20,815.72 
966.92 



2,403.74 



3,448.43 
2,074.59 



2,600.70 



7,100.68 

1,883.35 



37,932.98 
13,643.45 



2,479.47 
61.92 



156,014.02 



$ c. 
860.51 



2,476.87 
1,404.80 



296.77 



1,237.03 

55.37 



166.13 
872.12 



498.66 
8,479.39 

1,839.89 
790.05 
230.40 
942.76 

1,337.23 

7,891.50 



1,398.48 
301.34 



1,871.50 



350.21 
820.14 

4,295.94 
1,457^26 



5,822.27 
1,901.69 



72,277.37 



$ c 
860.51 



1.00 



175.43 



21,071.78 



565.44 
956.53 



4.05 



474.67 
30.00 



292.38 



281.26 
140.00 

100.84 

50.00 

440.00 



180.56 
30.00 



121.10 
96.08 



30.00 
698.81 



137.28 
20.00 

1,733.92 
42.64 



390.00 



187.90 

20.00 

155.17 



421.28 
26.99 



66,720.37 



*For townships included in rural power districts see "Cost of Power" and "Rural Operating' 
statements preceding. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



253 



SYSTEM 



E.O.— CREDIT OR CHARGE 



supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments 
or Charged to each Municipality in respect of power supplied in the year 
as a Credit or Charge to each municipality at October 31, 1933 



Interest at 4% per annum 
added during the year 


Net amount credited or charged 
in respect of power supplied in 
the year ending October 31, 1933 


Accumulated amount standing 

as a credit or charge on 

October 31, 1933 


Credited 


Charged 


Credited 


Charged 


Credit 


Charge 


$ c. 


$ c. 
11.50 


$ c. 
363.10 
905.53 
555.95 


$ c. 


$ c. 
351.60 

913.03 
569.49 


$ c. 


7 50 






13 54 










99.17 
56.19 


676.81 
358.53 


3,256.90 








1,819.52 


830 21 


2,282.28 


23,453.54 

684.71 

71.33 

944.68 




38 68 




290.89 






11.87 


379.97 




95 26 


1,261.94 
1,754.16 
17.42 
2,061.88 
1,358.31 

1,884.54 
296.86 






49.48 
2.21 




3,040.67 








75.00 


135 64 




1,240.93 
659.26 




82 98 










7.78- 
34.88 




2,159.29 








1,253.86 


104 05 


275.86 
106.50 


2,541.61 






19.95 
339.46 

73.60 
31.60 
10.43 
37.85 
53.49 

315.66 
1.70 




412.11 




6,654.30 

1,034.17 
912.43 
357.89 
786.04 
282.90 

4,256.36 

3,405.53 

757.17 

748.69 

251.91 




15.653.71 








2,977.66 








1,734.08 








719.82 








1,862.73 








1,673.62 








12,493.52 


283 44 




3,278.08 
1,201.51 




75 33 








56.56 
12.05 




2,341.01 








585.30 


1,514.79 


2,349.60 


40,063 45 




74.34 


1,449.40 
779.68 
795.39 
308.19 

1,752.95 

609.02 

289.41 

43.98 

2,757.09 

82.59 


3,262.45 


545.74 




13,409.51 






14.01 
32.81 

174.15 
58.29 




1,549.61 








1,161.14 








6,410.94 






2,144.57 


97.30 




2,132.19 
20.42 


2.48 










233.72 
76.13 




9,234 36 








2,087 40 










4,669.47 


2,379.86 


47,246.60 


44,997.40 


131,601.92 


88,975.05 



254 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 



EASTERN ONTARIO SYSTEM 
Reserve for Renewals — October 31, 1933 

Total provision for renewals to October 31, 1932 $3,952,009.03 

Deduct : 

Expenditures to October 31, 1932 895,690.00 

Balance brought forward at October 31, 1932 $3,056,319.03 

Renewals reserve in respect of Nipissing district transferred to 

Northern Ontario properties 215,038.84 

$2,841,280.19 
Added during the year ending October 31, 1933: 

Amounts charged to municipalities and rural power districts as 

part of the cost of power delivered to them $117,629 . 27 

Amounts included in the costs of distribution of power within 

rural power districts 62,925 .98 

Provision against equipment employed in respect of contracts 

with private companies which purchased power, and against 

equipment in local distribution systems 47,237 .84 

Provision against equipment in Campbellford Pulp Mill 1,051 .20 

Interest at 4 % per annum on the monthly balances at the credit 

of the account 1 13,614 . 69 

342,458.98 

$3,183,739.17 
Deduct : 

Expenditures during the year ending October 31, 1933 $40,199. 16 

Provision for renewals on lines transferred 912 .98 

41,112.14 

Balance carried forward October 31, 1933 $3,142,627.03 



1934 HYDRO-ELECTRIC POWER COMMISSION 255 



EASTERN ONTARIO SYSTEM 

Reserve for Obsolescence and Contingencies— October 31, 1933 

Balance brought forward at October 31, 1932 $1,314,734. 73 

Contingency reserve in respect of Nipissing district transferred to 

Northern Ontario properties 186,788.89 

$1,127,945.84 
Added during the year ending October 31, 1933: 

Amounts charged to municipalities and rural power districts as 

part of the cost of power delivered to them $36,376 .53 

Amount included in the costs of distribution of power within 

rural power districts. * 31,462 .99 

Provision against equipment employed in respect of contracts 

with private companies which purchased power, and local 

distribution systems 15,349 . 10 

Share of profits realized in respect of the sale of certain of the 

Commission's investment securities 4,671 .39 

Net profit from operation of local distribution systems and 

utilities 1,281 .64 

Interest at 4 % per annum on monthly balances at the credit of 

the account 45,117 .83 

134,259.48 

$1,262,205.32 
Deduct: 

Contingencies met with during the year ending October 31, 1933. . $121,516 .44 
Commission's share of American exchange paid during the year 
by the Province of Ontario on the transfer of funds to New 
York to meet capital retirements 9,579 . 66 

131,096.10 

Balance carried forward October 31, 1933 $1,131,109. 22 



256 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



EASTERN ONTARIO SYSTEM 



SINKING FUND 



Statement showing Sinking Fund paid by each Municipality in the periods mentioned 

hereunder as part of the cost of power delivered thereto, together with its 

proportionate share of other Sinking Funds, provided out of 

other revenues of the system, and interest allowed 

thereon to October 31, 1933 



Municipality 



Period 
of years 

ending 

Oct. 31, 

1933 



Amount 



Municipality 



Period 
of years 

ending 

Oct. 31, 

1933 



Amount 



Alexandria. . . . 
Apple Hill ... 

Athens 

Bath 

Belleville 

Bloomfield. . . . 
Bowmanville. . 

Brighton 

Brockville. . . . 
Cardinal 

Carleton Place 
Chesterville. . . 

Cobourg 

Colborne 

Deseronto . . . . 

Finch 

Hastings 

Havelock 

Kemptville. . . 
Lakefield 

Lanark 

Lancaster .... 

Lindsay 

Madoc' 

Marmora 

Martintown . . 

Maxville 

Napanee 

Norwood 

Oshawa 

Ottawa 

Perth 

Peterborough . 

Picton 

Port Hope. . . . 

Prescott 

Richmond 

Russell 

Smiths Falls. . 
Stirling 

Trenton 

Tweed 

Warkworth . . . 
Wellington . . . 
Westport 



9 years 

9 " 

5 " 

2 " 

5 " 

5 " 

2 " 

4 " 

13 " 
4 " 

9 " 

14 " 

2 " 
1 " 

3 " 



$ 

17,415. 

1,689. 

2,458. 

418. 

59,864. 

2,562. 
11,113. 

3,884. 
90,546. 

1,431. 

40,058. 
17,050. 

8,067. 
337. 

1,951. 

1,781. 
788. 
5,666. 
9,967. 
4,814. 

3,115. 
4,203 . 
34,998. 
2,479. 
2,136. 

1,082. 

5,041. 

14,478. 

2,711. 

186,135. 

52,227. 
34,151. 
117,464 
20,429 
17,960. 

25,550. 
894 

2,863 
52,428 

3,026 



2 " 


15,465.69 


3 " 


2,472.03 


5 " 


1,484.82 


5 " 


3,949.61 


2 " 


949.46 



Whitby 

Williamsburg 
Winchester . . 



Rural Power District 5 



Alexandria R.P.D 

Arnprior R.P.D 

Belleville R.P.D 

Bowmanville R.P.D... 
Brighton R.P.D 

Brockville R.P.D 

Campbellford R.P.D. 
Carleton Place R.P.D. 
Chesterville R.P.D... 
Cobourg R.P.D 

Colborne R.P.D 

Fenelcn Falls R.P.D. 

Iroquois R.P.D 

Kemptville R.P.D.. . . 
Kingston R.P.D 

Lakefield R.P.D 

Lindsay R.P.D 

Martintown R.P.D.. . 

Maxville R.P.D 

Millbrook R.P.D 

Napanee R.P.D 

Nepean R.P.D 

Newcastle R.P.D 

Norwood R.P.D 

Omemee R.P.D 

Oshawa R.P.D 

Perth R.P.D 

Peterborough R.P.D.. 

Prescott R.P.D 

Renfrew R.P.D 



Smiths Falls R.P.D.. 

Stirling R.P.D 

Trenton R.P.D 

Warkworth R.P.D.. . 
Wellington R.P.D. . 

Williamsburg R.P.D. 

Total 



5 years 

13 " 

14 " 



$ c. 

20,245.70 

2,473.15 

10,830.56 



1,073.35 

174.58 

7,434.78 

1,983.81 

502.34 

10,640.38 

1,938.64 

8.35 

6,884.82 

8,029.70 

2,410.26 

832.30 
6,414.85 

368.09 
7,752.11 

698.09 

383.77 

4,240.71 

5,414.70 

942.65 

5,420.16 

13,300.08 

1,782.62 

791.03 

93.90 

17,571.23 
479.37 

12,613.33 

6,094.34 

114.84 

4,706.98 
1,393.56 
2,419.56 
88 . 69 
5,302.85 

960.66 



1,064,379.57 



*For townships included in rural power districts see "Cost of Power" and "Rural Operating" 
statements preceding. 



1934 HYDRO-ELECTRIC POWER COMMISSION 257 



EASTERN ONTARIO SYSTEM 
Reserve for Sinking Fund — October 31, 1933 

Total provision for sinking fund to October 31, 1932. $857,536.86 

Sinking fund provision in respect of Nipissing district now transferred to Northern 

Ontario properties 469 . 75 

$857,067.11 

Provided in the year ending October 31, 1933: 

By charges included in the cost of power delivered to munici- 
palities and rural power districts $110,238.06 

By charges included in the costs of distribution of power within 

rural power districts 16,863 .37 

By charges against contracts with private companies which 

purchased power, and local distribution systems 45,928.35 

Interest at 4 % per annum on the amount standing at the credit 

of the reserve accounts. 34,282 .68 

207,312.46 

Total $1,064,379 .57 



258 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 



THUNDER BAY 

Operating Account for the Year 

Costs of operation as provided for under the terms of the Power Commission Act 

Costs of operation and maintenance, including the proportion of 
administrative expenses chargeable to the operation of this 
system : 

Generation and transmission equipment $211,219.87 

Rural power districts 3,509 . 95 

$214,729.82 

Interest (including exchange thereon) on capital investment in: 

Generation and transmission equipment $970,562 . 19 

Rural power districts 2,307 . 24 

972,869.43 

Provision for renewals of: 

Generation and transmission equipment $147,780 . 23 

Rural power districts 1 , 738 . 59 

149,518.82 

Provision for obsolescence and contingencies in respect of: 

Rural power districts $869 . 29 

869.29 

Provision for sinking fund: 

By charges included in the cost of power delivered to munici- 
palities and rural power districts $105,741 .76 

By charges against contracts with private companies which 

purchased power 34,794 . 54 

By charges included in the cost of distribution of power within 

rural power districts 457 . 68 

140,993.98 

$1,478,981.34 



1934 HYDRO-ELECTRIC POWER COMMISSION 259 



SYSTEM 

Ending October 31, 1933 

Revenue for period 

Amount received from (or billed against) each municipality by the 

Commission $1 ,049,329. 42 

Power sold to private companies 321,494.51 

Amounts received from (or billed against) customers in rural power 

districts 9,275 .86 



-$1,380,099.79 



Add: 

Amounts due by certain municipalities, being the difference 
between the sums received (or billed) at interim rates and 
the amounts charged — following annual adjustment — in 
respect of power supplied in the year $95,683 . 25 

Amounts due by municipalities comprising certain rural power 
districts, being the difference between the sums received 
from (or billed against) customers therein and the amounts 
charged to such districts — following annual adjustment — in 
respect of power supplied in the year 3, 198 . 30 



98,881.55 



Revenue $1,478,981.34 



$1,478,981.34 



260 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



THUNDER BAY 

Statement showing the amount to be paid by each Municipality as the Cost — under 

received by the Commission from each Municipality on account of such cost; 

tainment (by annual adjustment) of the actual cost 



Municipality 



Interim rate 
per horsepower 
collected by 
Commission 
during year 



To 

Jan. 1, 

1933 



To 

Oct. 31, 

1933 



Share of 

capital cost 

of system 

on which 

interest and 

fixed 

charges are 

payable 



Average 
horse- 
power 
supplied 
in year 
after cor- 
rection 
for power 
factor 



Share of operating 



Operating, 
main- 
tenance 

and 
adminis- 
trative 
expenses 



Interest 
(including 
exchange) 



Fort William 

Port Arthur 

Township of Nipigon 

Rural Power Districts 



$21.00 plus transfor 
mation charges. . . 

$21.00 plus transfor 
mation charges. . . 

$30.00.. . .$28.00.. . . 



Fort William R.P.D. — Neebing, Paipoonge 

and Oliver twps 

Port Arthur R.P.D. — Shuniah twp 



Totals — Municipalities 

Totals — Rural power districts. 
Totals — Ccmpanies 



Non-operating capital 
Grand totals 



$ c. 

3,298,120.77 

10,514,944.79 
24,657.61 



24,854.93 
12,444.24 



13,837,723.17 

37,299.17 

4,633,001.68 



18,508,024.02 
68,809.15 



18,576,833.17 



10,221.5 

33,019.9 

83.5 



69.1 
31.8 



43,324.9 

100.9 

14,783.3 



58,209.1 



$ c. 

39,264.12 

120,311.40 
1,379.54 



569.80 
389.65 



160,955.06 

959.45 

49,305.36 



,219.87 



$ c. 

173,083.04 

551,451.75 
1,296.81 



1,314.87 
609.49 



725,831.60 

1,924.36 

242,806.23 



970,562.19 



THUNDER BAY SYSTEM— 

Statement showing the costs of distribution of power within each Rural Power 
and the amounts remaining to be credited to certain Districts or charged 

(by annual adjustment) of the actual 



District and municipalities 
comprised therein 



Total capital cost of each district, 
Provincial Government grant 
received and applied thereagainst, 
and the balance representing the 
investment by the Commission 



Total 

capital 

cost 



Govern- 
ment 
grant 



Com- 
mission's 
investment 



Cost of 

power 

delivered 

to districts 

as shown 

in "cost of 

power" 

table 

preceding 



Fort William R.P.D. — Neebing, Oliver and 

Paipoonge twps 

Port Arthur R.P.D.— Shuniah twp 


$ c. 

60,963.67 
46,914.36 


$ c. 

30,481.84 
23,457.18 


$ c. 

30,481.83 
23,457.18 


$ c. 

2,367.59 
1,223.82 


Totals 


107,878.03 


53,939.02 


53,939.01 


3,591.41 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



261 



SYSTEM 



T.B.—COST OF POWER 



the Power Commission Act — of Power supplied to it by the Commission; the amount 
and the amount remaining to be charged to each Municipality upon ascer- 
of power supplied to it in the year ending October 31, 1933 



costs and fixed charges 



Renewals 



Sinking 
fund 



Cost in 
excess of 

revenue 
from power 

sold to 

private 
companies 



Total cost 

of power 

for year as 

provided to 

be paid 

under 

Power 

Commission 

Act 



Amounts 
received 

from 

(or billed 

against) 

each 

municipality 

by the 
Commission 



Amounts remaining to 
be charged to each muni- 
cipality upon ascertain- 
ment of actual cost of 
power by annual adjust- 
ment 



$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


26,806.95 


25,229.63 


9,735.17 


274,118.91 


251,129.95 


22,988.96 


84,515.37 
187.78 


80,040.60 

182.13 


31,448.85 
79.53 


867,767.97 

3,125.79 


795,677.92 

2,521.55 


72,090.05 
604 . 24 


219.61 
102.49 


197.50 
91.90 


65.81 
30.29 


2,367.59 
1,223.82 


2,367.59 
1,223.82 


see below 


111,510.10 
322.10 


105,452.36 

289.40 

34,794.54 


41,263.55 

96.10 

. (41,359.65) 


1,145,012.67 

3,591.41 

321,494.51 


1,049,329.42 

3,591.41 

321,494.51 


95,683.25 


35,948.03 




147,780.23 


140,536.30 




1,470,098.59 
Net Charge. . . 


1,374,415.34 


95,683.25 
95,683.25 











RURAL POWER DISTRICTS 



T.B.— RURAL OPERATING 



District, the revenues collected from (or charged to) customers within each District, 
to the Municipalities comprising certain other Districts upon ascertainment 
costs in the year ending October 31, 1933 



Distribution costs and fixed charges 



Cost of 
operation, 
mainten- 
ance and 
adminis- 
tration 



Interest 
(including 
exchange' 



Renewal 
charges 



Obsoles- 
cence and 
contin- 
gencies 



Sinking 
fund 



Total 
cost 



Revenue 

from 
power and 

light 

customers 

in each 

district 



Amounts remaining 
to be credited to 
certain districts or 
charged to the 
municipalities com- 
prising certain other 
districts 



Credited 



Charged 



$ c. 

2,113.14 
1,396.81 


$ c. 

1,661.95 
645 . 29 


$ c. 

1,250.95 
487.64 


$ c. 

625.47 
243.82 


$ c. 

329.31 
128.37 


$ c. 

8,348.41 
4,125.75 


$ c. 

6,870.52 
2,405.34 


$ c. 


$ c. 

1,477.89 
1,720.41 


3,509.95 


2,307.24 


1,738.59 


869 . 29 


457.68 


12,474.16 


9,275.86 




3,198.30 



262 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



THUNDER BAY 

Statement showing the net Credit or Charge to each Municipality in respect of power 

made and interest added during the year. Also the net amount Credited 

ending October 31, 1933, and the accumulated amount standing 



Municipality 



Date 

commenced 

operating 



Net credit or charge 
at October 31, 1932 



Credit 



Charge 



Cash receipts and pay- 
ments on account of 
such credits andcharges, 
also adjustments made 
during the year 



Credited 



Charged 



Fort William 

Nipigon twp 

Port Arthur 


Oct., 
Jan., 
Dec, 

Oct., 
Jan., 


1926 
1925 
1910 

1932 
1932 


$ c. 
891.63 


$ c. 
24,527.56 


$ c. 
24,527.56 


$ c. 
891.63 


137,165.48 
123.34 


137,165.48 




Rural Power Districts* 
Fort William R.P.D 




40.00 


Port Arthur R.P.D 


0.88 














Totals 




892.51 


161,816.38 


161,693.04 


931.63 









*For townships included in rural power districts see "Cost of Power" and "Rural Operating" 
statements preceding. 



THUNDER BAY SYSTEM 
Reserve for Renewals — October 31, 1933 

Total provision for renewals to October 31, 1932 $1,144,179.30 

Deduct: 

Expenditures to October 31, 1932 3,656.90 

Balance brought forward October 31, 1932. $1,140,522.40 

Added during the year ending October 31, 1933: 

Amounts charged to municipalities and rural power districts as 

part of the cost of power delivered to them $111,832.20 

Amounts included in the costs of distribution of power within 

rural power districts 1,738.59 

Provision against equipment employed in respect of contracts 

with private companies which purchased power 35,948.03 

Reserve provided in respect of equipment transferred 793 . 19 

Interest at 4 % per annum on monthly balances at the credit of 

the account 45,650.65 

195,962.66 

$1,336,485.06 
Deduct: 

Expenditures during the year ending October 31, 1933 11,165 .57 

Balance carried forward October 31, 1933 $1,325,319.49 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



263 



SYSTEM 



T.B.— CREDIT OR CHARGE 



supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments 
or Charged to each Municipality in respect of power supplied in the year 
as a Credit or Charge to each Municipality at October 31, 1933 



Interest at \ ( " ( per annum 
added during the year 


Net amount credited or charged 
in respect of power supplied in 
the year ending October 31, 1933 


Accumulated amount standing 

as a credit or charge on 

October 31, 1933 


Credited 


Charged 


Credited 


Charged 


Credit 


Charge 


$ c. 


$ c. 
376.31 


$ c. 


$ c. 
22,988.96 

604 . 24 
72,090.05 

1,477.89 
1,720.41 


$ c- 


$ c. 
23,365.27 


16.43 






587.81 




1,884.32 
4.93 






73,974.37 








1,646 16 


0.03 






1,719 50 












16.46 


2,265.56 




98,881.55 




101,293.11 











THUNDER BAY SYSTEM 
Reserve for Obsolescence and Contingencies— October 31, 1933 

Balance brought forward October 31, 1932 $711,241 .06 

Added during the year ending October 31, 1933: 

Amount included in the costs of distribution of power within 

rural power districts $869 . 29 

Share of profits realized in respect of the sale of certain of the 

Commission's investment securities 2,527 . 1 1 

Interest at 4 % per annum on monthly balances at the credit of 

the account 28,449 .64 

31,846.04 

$743,087.10 

Deduct: 

Commission's share of American exchange paid during the year 
by the Province of Ontario on the transfer of funds to New 
York to meet capital retirements 27,690 . 79 

Balance carried forward October 31, 1933 $715,396.31 



264 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



THUNDER BAY SYSTEM 



T.B.— SINKING FUND 



Statement showing Sinking Fund paid by each Municipality in the periods mentioned 

hereunder as part of the cost of power delivered thereto, together with 

its proportionate share of other sinking funds provided out 

of other revenues of the system, and interest 

allowed thereon to October 31, 1933 



Municipality 


Period of years ending 
October 31, 1933 


Amount 


Fort William 

Port Arthur 

Township of Nipigon 

Rural Power Districts* 

Fort William R.P.D 

Port Arthur R.P.D 


7 years 

7 " 
7 " 

2 years 

2 " 


$ c. 

239,785.83 

821,761.42 

1,439.22 

611.43 

355.55 


Total 


1,063,953.45 



*For townships included in rural power districts see "Cost of Power" and "Rural Operating' 
statement preceding. 



ACCOUNT WITH THE PROVINCIAL TREASURER— NIAGARA AND 



Feb. 8, 1933 Cash returned to the Province in the year ending 

June 19, 1933 October 31, 1933, to cover the difference between 

Aug. 8, 1933 advances by the Province to the Commission 

and the capital expenditures made out of such 

advances by the Commission in the year ending 

October 31, 1932 

Feb. 8, 1933 Repayment to the Province of the investment — 
according to book values — in the distribution 
system in Cobourg (in the former Central Ontario 
System) upon the sale of these properties to the 
municipality 

April 30, 1933 Paid on account of interest and exchange $5,274,086.46 

Oct. 31, 1933 Cheque to cover balance of interest and exchange 

for year ending October 31, 1933 5,326,005 .30 

Oct. 31, 1933 Payment under debt retirement plan 

Oct. 31, 1933 Balance carried down 



$339,473.57 



451,585.69 



10,600,091.76 
2,155,176.38 
187,964,549.41 
$201,510,876.81 



1934 HYDRO-ELECTRIC POWER COMMISSION 263 

THUNDER BAY SYSTEM 
Reserve for Sinking Fund — October 31, 1933 

Total provision for sinking fund to October 31, 1932 $887,461 .03 

Provided in the year ending October 31, 1933: 

By charges included in the cost of power delivered to munici- 
palities and rural power districts $105,741 . 76 

By charges included in the costs of distribution of power within 

rural power districts 457 . 68 

By charges against contracts with private companies which 

purchased power 34,794 . 54 

Interest at 4 % per annum on amounts standing at the credit of 

the reserve accounts 35,498 . 44 

176,492.42 

Total ' $1,063,953.45 



OTHER SYSTEMS—FOR THE YEAR ENDING OCTOBER 31, 1933 

Oct. 31, 1932 Cash advances to date for the purposes of 

Niagara and other Power Systems $204,488,631.44 

Less repayments to that date under debt retire- 
ment plan 14,853,440.35 

$189,635,191 .09 

Nov. 1, 19321 

to \ Sundry cash advances 1,275,593 .96 

Oct. 31, 1933 J 

Oct. 31, 1933 Interest for year on all cash advances $10,522,687.93 

Oct. 31, 1933 Commission's share of American exchange paid 
during the year by the Province of Ontario 
on the transfer of funds to New York to meet 
interest and capital retirements 819,433 . 15 

$11,342,121.08 
Less — Interest credited by Province on repay- 
ments made by Commission 742,029.32 

10,600,091 . 76 

$201,510,876.81 

Nov. 1, 1933 Total cash advances $204,973,166. 14 

Less — Payments made under debt retirement plan 17,008,616.73 

$187,964,549.41 



266 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

NORTHERN ONTARIO 

Embracing the Nipissing, Wahnapitae, Abitibi- 

Operating Account for the 

Cost of Operation 
Power purchased: 

For Abitibi-Sudbury District to May 25, 1933, after which date power was 

supplied from No. 1 unit of the Abitibi Canyon development $118,246.57 

Costs of operation and maintenance, including the proportion of administrative 

office expense chargeable to the operation of these properties 286,942 .24 

Interest (including exchange thereon) on capital investment in generation and 

transmission equipment 371,264.32 

Provision for renewals of generation and transmission equipment 99,669.57 

Provision for obsolescence and contingencies 31,316.85 

Total costs of operation . ... $907,439.55 

Operating surplus for year 20,258 . 19 

$927,697.74 

Provision — to extent of surplus available — for depreciation on Hunta-Copper Cliff 

line for period prior to November 1, 1932 $20,258 . 19 

Note. — Interest on expenditures on Abitibi Canyon development capitalized during construction. 



NORTHERN ONTARIO PROPERTIES 

Embracing the Nipissing, Wahnapitae, Abitibi-Sudbury and Patricia 
(Ear Falls) Districts 

Reserve for Renewals — October 31, 1933 

Total provision for renewals to October 31, 1932 $339,105 .54 

Deduct expenditures to October 31, 1932 51,379.73 

Amount of reserves at October 31, 1932 $287,725 .81 

Added during the year ending October 31, 1933 $119,927 . 76 

Interest at 4 per cent, per annum on monthly balances at the credit of 

the account 1 1 ,509 . 04 

131,436.80 

$419,162 61 

Deduct expenditures during the year ending October 31, 1933 5,483 .51 

Balance carried forward October 31, 1933 $413,679 . 10 



1934 HYDRO-ELECTRIC POWER COMMISSION 267 

PROPERTIES 

Sudbury and Patricia (Ear Falls) Districts 

Year Ending October 31, 1933 

Revenue for Period 
Power sold to private companies and customers $927,697 . 74 



$927,697.74 



Operating surplus for year brought down $20,258 . 19 



NORTHERN ONTARIO PROPERTIES 

Embracing the Nipissing, Wahnapitae, Abitibi-Sudbury and Patricia 
(Ear Falls) Districts 

Reserve for Obsolescence and Contingencies — October 31, 1933 

Amount of reserves to October 31, 1932 $175,744 . 75 

Added during the year ending October 31, 1933 $31,316.85 

Share of profits realized in respect of the sale of certain of the Commis- 
sion's investment securities 789 . 93 

Interest at 4 per cent, per annum on monthly balances at the credit of 

the account 7,029.79 

39,136.57 

$214,881.32 
Deduct: 

Contingencies met with during the year ending October 31, 1933 $648.00 

Commission's share of American exchange paid during the year by 
the Province of Ontario on the transfer of funds to New York 

to meet capital retirements 2,629 . 86 

3,277.86 

Balance carried forward October 31, 1933 $211,603.46 



268 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NORTHERN ONTARIO 

Nipissing Rural Power Districts — 

Statement showing the costs of distribution of power within each Rural Power 
and the amounts remaining to be credited to certain Districts or charged to 

annual adjustment) of the actual costs 





Total capital cost of each district, 
Provincial Government grant 
received and applied thereagainst, 
and the balance representing the 
investment by the Commission 




District and municipalities 
comprised therein 


Cost of 
power 




Total 

capital 

cost 


Govern- 
ment 
grant 


Com- 
mission's 
investment 


North Bay R.P.D.— West Ferris and Widdi- 
field twps 


$ c. 

32,565.04 
5,202.30 


$ c. 

15,911.74 
2,601.15 


$ c. 

16,653.30 
2,601.15 


$ c. 
3,993.41 


Powassan R.P.D. — Himsworth South twp.. 


121.97 


Totals 


37,767.34 


18,512.89 


19,254.45 


4,115.38 



NORTHERN ONTARIO 
Nipissing Rural Power Districts — 

Statement showing the net Credit to each Municipality in respect of power supplied 
Credited to each Municipality in respect of power supplied in the year 

to each Municipality 



Rural power district 


Date 

commenced 

operating 


Net credit at 
October 31, 1932 




Credit 


North Bay R.P.D. — West Ferriss and Widdifield 

twps 

Powassan R.P.D. — Himsworth South twp 


June, 19^7 
Nov., 1931 


$ c. 

7,571.06 
41.05 


Totals 




7,612.11 









1934 



HYDRO-ELECTRIC POWER COMMISSION 



269 



PROPERTIES 



N I PISSING RURAL 



Rural Operating 

District, the revenues collected from (or charged to) customers within each District, 
the Municipalities comprising certain other Districts upon ascertainment (by 
in the year ending October 31, 1933 



Distribution costs and fixed charges 


Total 
cost 


Revenue 

from 
power and 

light 

customers 

in each 

district 


Amounts remaining 
to be credited to 


Cost of 
operation, 
mainten- 
ance and 
adminis- 
tration 


Interest 
(including 
exchange) 


Renewal 
charges 


Obsoles- 
cence and 
contin- 
gencies 


Sinking 
fund 


certain districts or 
charged to the 
municipalities com- 
prising certain other 
districts 


Credited 


Charged 



$ c. 

2,733.64 
84.99 


$ c. 

799.00 
127.80 


$ c. 

621.67 
101.73 


$ c. 

310.83 
50.87 


$ c. 

167.44 
26.78 


$ c. 

8,625.99 
514.14 


$ c. 

9,627.44 
583.85 


$ c. 

1,001.45 
69.71 


$ c. 


2,818.63 


926.80 


723.40 


361.70 


194.22 


9,140.13 


10,211.29 


1,071.16 





PROPERTIES 
Credit or Charge 



NI PISSING RURAL 



to it to October 31, 1932, the interest added during the year; also the net amount 
ending October 31, 1933, and the accumulated amount standing as a Credit 
at October 31, 1933 



Interest at 4 % per annum 
added during the year 



Net amount credited in respect 

of power supplied in the year 

ending October 31, 1933 



Accumulated amount standing 

as a credit on October 31, 

1933 



Credited 


Credited 


Credit 


$ c. 

302 . 84 
1.64 


$ c. 

1,001.45 
69.71 


$ c. 

8,875.35 
112.40 


304.48 


1,071.16 


8,987.75 



270 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



NORTHERN ONTARIO 

Nipissing Rural Power Districts — Reserve for Renewals 
—October 31, 1933 

Total provision for renewals to October 31, 1932 $2,958 .59 

Added during the year ending October 31, 1933 723 .40 

Interest at 4 per cent, per annum on monthly balances at the credit of the account 118.34 

Balance carried forward October 31, 1933. $3,800.33 



Nipissing Rural Power Districts— Sinking Fund 

Statement showing Sinking Fund paid by each Rural Power District in the periods 

mentioned hereunder, as part of the cost of power delivered thereto, 

and interest allowed thereon to October 31, 1933 



Rural power district 


Period of years 

ending 

October 31, 1933 


Amount 


North Bay R.P.D. — West Ferris and Widdifield twps 

Powassan R.P.D. — Himsworth S. twp 


4 years 

2 >; 


$ c. 

634.76 

48.00 


Total 




682.76 









NORTHERN ONTARIO 

Manitoulin Island Rural Power 

Statement showing the costs of distribution of power within Rural Power District, 
amount remaining to be charged to the Municipalities comprising 

costs in the year ending 





Total capital cost of each district, 
Provincial Government grant 
received and applied thereagainst, 
and the balance representing the 
investment by the Commission 




District and municipalities 
comprised therein 


Cost of 




Total 

capital 

cost 


Govern- 
ment 
grant 


Com- 
mission's 
investment 


power 
purchased 


Manitoulin R.P.D. — Gordon Allan, Billings 
and Carnarvon twps., Town of Gore Bay 
and Indian Reserve 


$ c. 
59,970.48 


$ c. 
27,344.69 


$ c. 
32,625.79 


$ c. 
3,281.25 



934 



HYDRO-ELECTRIC POWER COMMISSION 



27 



PROPERTIES NIPISSING RURAL 

Nipissing Rural Power Districts — Reserve for Obsolescence and Contingencies 

—October 31, 1933 

Amount of reserves to October 31, 1932 . $919.50 

Added during the year ending October 31, 1933 361 . 70 

Interest at 4 per cent, per annum on monthly balances at the credit of the account 36.78 

Balance carried forward October 31, 1933 $1,317.98 



Nipissing Rural Power Districts — Reserve for Sinking Fund, October 31, 1933 



Total provision for sinking fund to October 31, 1932 $469 . 75 

Provided in the year ending October 31, 1933: 

By charges included in the costs of distribution of power within rural 

power districts $194 . 22 

Interest at 4 % per annum on the amount standing at the credit of the 

reserve accounts 18 . 79 

213.01 

$682.76 



PROPERTIES 

District — Rural Operating 



MANITOULIN RURAL 



the revenues collected from (or charged to) customers within the District, and the 
this District upon ascertainment (by annual adjustment) of the actual 
October 31, 1933 



Distribution costs and fixed charges 




Total 
cost 


Revenue 

from 
power and 

light 

customers 

in each 

district 


Amounts remaining 
to be credited to 


Cost of 
operation, 
mainten- 
ance and 
adminis- 
tration 


Interest 
(including 
exchange) 


Renewal 
charges 


Obsoles- 
cence and 
contin- 
gencies 


Sinking 
fund 


certain districts or 
charged to the 
municipalities com- 
prising certain other 
districts 


Credited 


Charged 


$ c. 
1,447.26 


$ c. 
1.434.09 


$ c. 
996.29 


$ c. 
476.90 


$ c. 
285.45 


$ c. 
7,921.24 


$ c. 
6,537.40 


$ c. 


$ c. 
1,383.84 









272 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 



GUELPH 
Operating Account for 

Expenditure 

Transportation expense $23,745 .09 

Maintenance — way and structures 6,747 .34 

Maintenance — equipment 15,566 .45 

Electric power and motor fuel 9,469 .67 

General opeiating and management expenses, including a proportion 
of administrative and accounting expenses of the Commission 

chargeable to the operation of the railway 10,577 .01 

Insurance 3,700 .83 

Taxes 353 . 89 

$70,160.28 

Interest 13,768.35 

Provision for instalments payable to the City of Guelph on May 1, 

1933, and November 1, 1933, under purchase agreement: 

Interest for year. . $3,349.36 

On account of principal 8,350 . 64 

11,700.00 

Provision for sinking fund 3, 159 . 00 

$98,787.63 



GUELPH RADIAL RAILWAY 
Reserve for Renewals — October 31, 1933 

Total provision for renewals to October 31, 1932 $55,793 .41 

Deduct: 

Expenditures to October 31, 1932 24,860.19 

Balance brought forward October 31, 1932 ' . . . $30,933 . 22 

Added during the year ending October 31, 1933: 

Interest at 4 % on the monthly balances at the credit of the account 1,237.33 

$32,170.55 
Deduct: 

Expenditures during the year ending October 31, 1933 697.57 

Balance carried forward October 31, 1933 $31,472.98 



1934 HYDRO-ELECTRIC POWER COMMISSION 273 



RADIAL RAILWAY 

the Year Ending October 31, 1933 

Revenue 

Operating revenue $57,455 .31 

Net deficit for year payable by the City of Guelph 41,332 .32 



$98,787.63 



GUELPH RADIAL RAILWAY 

Reserve for Sinking Fund— October 31, 1933 

Total provision for sinking fund to October 31, 1932 $4,801.68 

Provided in the year ending October 31, 1933 3,159.00 

Interest at 4 % on the monthly balances at the credit of the account 192 . 07 



Balance carried forward October\31, 1933 $8,152 .75 



274 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

THE HAMILTON STREET 

A Subsidiary of the Hydro-Electric 

Balance Sheet — 

Assets 

Properties, road, equipment, motor buses, franchises, etc., as shown 

in the books of the Company $4,777,945.79 

Less — Reserves for renewal — 

Of properties, road and equipment $695,341 . 72 

Of motor buses (fully covered) 189,586.94 

884,928.66 

$3,893,017.13 

Expenditures by Company in respect of T.H. & B. subway at James Street — 
carried forward pending final allocation of total cost of subway by Dominion 

Railway Board 20,932 . 78 

Materials and supplies 56,652 . 25 

Cash in bank $12,438.70 

Cash in hands of conductors and other employees 10,940.00 

23,378.70 

Accounts receivable — Less reserve for doubtful accounts 5,687 .93 

Taxes and insurance prepaid 6,699 . 08 

$4,006,367.87 



THE HAMILTON STREET 

A Subsidiary of the Hydro -Electric 

Statement of Revenue and Expenditure — 

Expenditure 

Transportation expenses $311,303 . 17 

Maintenance — Way and structures 50,568 . 84 

Maintenance — Equipment 100,968 .86 

Power and motor fuel — including power purchased 177,362 . 25 

General operating and management expenses, including a proportion of adminis- 
trative and accounting expenses of the Commission chargeable to the operation 

of the railway 49,945 . 13 

Taxes 56,761 .03 

Insurance — Fire, accident and liability 40,117.96 

Total operating expenses $787,027 . 24 

Net profit for year, before provision for renewal of road and equipment 27,307 .72 

$814,334 96 



1934 HYDRO-ELECTRIC POWER COMMISSION 275 

RAILWAY COMPANY 

Power Commission of Ontario 

October 31, 1933 

Liabilities 

Issued— 64,100 shares of a par value of $50.00 each $3,205,000.00 

Capital surplus — Created by advances to the Company by Dominion 
Power & Transmission Company Limited, prior to 3 1st December, 

1929 488,846.85 

$3,693,846.85 

Profit and loss account at October 31st, 1932 $21,929 59 

Less charges thereagainst in the last fiscal year 3,968 .35 

17,961.24 

Hydro-Electric Power Commission of Ontario — 

Cash advances 250,837 . 27 

Accounts payable and accrued charges , 37,922.51 

Reserve for outstanding tickets 5,800 . 00 

Contingent liability — 

Share of cost of T.H. & B. subway at James Street expected to be 
found payable by Company upon final allocation of total 
cost of subway by Dominion Railway Board. 

$4,006,367.87 



RAILWAY COMPANY 

Power Commission of Ontario 

For the Year ending October 31, 1933 

Revenue 

Passenger $799,074 . 63 

Freight and express 2,961 . 80 

Miscellaneous 12,298.53 

Total Revenue $814,334.96 



$814,334.96 



Note: 

Interest on Commission's advances to, and investment in capital stock of, the 

Hamilton Street Railway Company $164,220 .43 

in excess of profit for year (before provision for renewal of road and equip- 
ment) from operation of the street railway 27,307 . 72 

a balance of $136,912.71 

has been charged to the contingency reserve of the Niagara system. 



276 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

APPROPRIATIONS, ADVANCES AND CAPITAL EXPENDITURES 
For the Year Ending October 31, 1933 



Appropriations made by the Legislature for the purposes of the Commission, Cash 

Advances by the Province to the Commission on account of such appropriations, 

and the Capital Expenditures made on each Undertaking and System 

by the Commission out of such Cash Advances in the Year 

Ending October 31, 1933 



NIAGARA SYSTEM 

Appropriations by Legislature: 

For power developments, including Chats Falls $730,000.00 

For transformer and distributing stations 550,000 .00 

For transmission lines and rural distribution systems 600,000.00 

For miscellaneous 350,000 . 00 

$2,230,000.00 

Cash advances to the Commission out of such appropria- 
tions $1,294,785 . 00 

Deduct: Amount returned to the Province on October 

31, 1933 500,000.00 

$794,785.00 

Unexpended balance as at October 31, 1933, returnable to Province. 294,591.31 

$500,193.69 

Capital expenditure by the Commission: 

On Chats Falls development $289,262 .38 

On Ontario Power development „ 4,546 . 77 

On steel-tower lines 7,680 . 73 

On wood-pole lines 17,201 .56 

On transformer stations 101,318.35 

On Eastern transformer stations 168,532 .37 

On Eastern right-of-way 113,078.46 

On rural power districts 184,551 . 19 

On local distribution systems 9,179.56 

$895,351 .37 
On Queenston-Chippawa development — 

Receipts in excess of expenditures $35,294.98 

On right-of-way — 

Receipts in excess of expenditures 37,280. 19 

On Eastern transmission lines — 

Receipts in excess of expenditures 322,582.51 

395,157.68 
$500,193.69 



GEORGIAN BAY SYSTEM 

Appropriations by Legislature $405,000.00 

Cash advances to the Commission out of such appropriations $89,042.00 

Unexpended balance as at October 31, 1933, returnable to the Province 23,422 .53 

Capital expenditure by the Commission: 

On power developments $8, 743 . 56 

On transformer stations 5,931 .46 

On transmission lines 13,-505.96 

On rural power districts 40,229.60 

s $68,410.58 
On local distribution systems — 

Receipts in excess of expenditures 2,791 .11 



$65,619.47 



$65,619.47 



1934 HYDRO-ELECTRIC POWER COMMISSION 277 

EASTERN ONTARIO SYSTEM 

Appropriations by Legislature $305,000 .00 



Cash advances to the Commission out of such appropriations $94,000.00 

Unexpended balance as at October 31, 1933, returnable to the Province 14,096 .46 

Capital expenditure by the Commission: 

On power developments $2,792 .34 

On transformer stations 415 74 

On rural power districts , . 71,837.55 

On local distribution systems 4,290 .91 

On rural lines 1,238.53 

$80,575.07 
On transmission lines — 

Receipts in excess of expenditures 671 .53 



$79,903 . 54 



$79,903.54 



THUNDER BAY SYSTEM 

Appropriations by Legislature and by Treasury Board minute $206,000.00 

Cash advances to the Commission out of such appropriations and 

Treasury Board minute $149,000.00 

Expended out of renewals and other reserve funds of the system 1,033 .67 

Capital expenditure by the Commission: 

On transmission lines $8,699 . 19 

On transformer stations 119,221 .50 

On rural power districts 32,804 . 16 

$160,724.85 
On power developments — 

Receipts in excess of expenditures 10,691 . 18 



$150,033.67 



$150,033.67 



NORTHERN ONTARIO PROPERTIES 
ABITIBI CANYON DEVELOPMENT 

Appropriations by Legislature Nil 

Cash received by the Commission upon purchase from the Receiver 
of the Assets covered by the Bond Mortgage of Ontario Power 
Service Corporation, Limited $2,697,392.69 

Unexpended balance as at October 31, 1933 897,167 .55 

$1,800,225. 14 

Capital expenditure by the Commission: 

On purchase of the above mentioned assets, in cash $290,150.00 

This is additional to the $17,625,125.00 twenty year bonds of 

the Commission, guaranteed by the Province, bearing interest 

at 334 per cent, for the first five years, 4 percent, for the next 

five years and 5 per cent, for the last ten years. 
Toward completion of the development and on account of 

expenses incidental to the purchase 1,452,668.92 

In settlement of contractors' and other claims. . . 57,406 . 22 

$1,800,225. 14 



278 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

NORTHERN ONTARIO PROPERTIES— Continued 

AND 

MANITOULIN RURAL POWER DISTRICT 

Appropriations by Legislature and by Treasury Board Minute $255,690.96 



Cash advances to the Commission out of such appropriations 

and Treasury Board Minute $88,766 .96 

Deduct: Amount returned to Province on August 8, 1933. . . . 5,428.83 

— $83,338.13 

Deduct: Capital expenditure in the year ending October 31, 
1932, in excess of cash advances by the Province: 

(a) In respect of Northern Ontario Properties $45,153.78 

(b) In respect of Manitoulin Rural Power District.. . 1,119.61 

46,273.39 



$37,064.74 
Expended out of renewals and other reserve funds of the 

Commission 3,723 . 72 

$40,788.46 

Capital expenditure by the Commission on Northern Ontario 
Properties: 

On power development — Wahnapitae district $10,584 . 13 

On transformer stations — Wahnapitae district 2,141 .94 



$12,726.07 
On transmission lines — Wahnapitae district 

Receipts in excess of expenditures 2,756 .39 

$9,969.68 

On transmission lines — Hunta-Copper Cliff 8,070 . 70 

On transmission lines — Nipissing district $375 .98 

On local distribution systems — Nipissing district 4.627 .85 

On rural power districts — Nipissing district 1,932.37 



$6,936.20 
On power development — Nipissing district 

Receipts in excess of expenditures $649.27 

On transformer stations — Nipissing district 

Receipts in excess of expenditures 88 .59 



737.86 

6,198.34 



$24,238 



7 1 



On power development — Patricia district (Ear Falls) 

Receipts in excess of expenditures 956 . 44 



$23,282.28 



Capital expenditure by the Commission on Manitoulin Rural 
Power District: 

On transformer stations — Manitoulin district $4,989.76 

On rural power districts — Manitoulin district 12,516.42 

17,506.18 

$40, 78?. 46 



MISCELLANEOUS 

Appropriations by Legislature $1 .000,000. 00 



Cash advances to the Commission out of such appropriations $60,000.00 

Unexpended balance as at October 31, 1933, returnable to Province.. 10,008.50 



$49,991.50 



Capital expenditure by the Commission: 

On preliminary engineering and architects' plans for proposed 

new administration building $46,860 . 24 

On service building and equipment 3,131 .26 



$49,991.50 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



279 



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1934 HYDRO-ELECTRIC POWER COMMISSION 281 



SECTION X 



MUNICIPAL ACCOUNTS 

And Statistical Data Relating to Hydro-Electric Distribution Systems 

Operated by Individual Municipalities Served by 

The Hydro-Electric Power Commission 

The Municipal Accounts section of this report presents in summary, and 
individually, the results of the operation of the local electrical utilities in muni- 
cipalities owning their own distributing system and operating with energy 
supplied by or through the Hydro-Electric Power Commission. 

Financial statements prepared from the books of these "Hydro" utilities 
are submitted herein, to show how each has operated during the past year, 
and its financial status at the present time. Other tables give useful statistical 
information respecting average costs for the various classes of service and the 
rates in force. 

The books of account of the electrical utilities in all municipalities which 
have contracted with the Hydro-Electric Power Commission of Ontario for a 
supply of power are kept in accordance with an accounting system designed by 
the Commission. During the year 1933, this standard method of accounting 
was installed in Mildmay and Colborne. 

Periodical inspections are made of the books of all "Hydro" electrical 
utilities and local officials are assisted in the improvement of their office routine 
with a view to standardizing, as far as possible, the methods employed. In the 
majority of the smaller municipalities much of the bookkeeping for the electrical 
utilities is performed by representatives of the municipal audit department of 
the Commission as a measure of economy. This arrangement insures the correct 
application of the standard accounting system, with resultant uniformity in 
classification of revenues and expenditures; secures true reflections of the actual 
operating results for the year, and greatly enhances the comparative values of 
the reports. 

The first financial statement in this section presents consolidated balance 
sheets for each year since 1912, and thus shows the march of progress. It 
combines the balance sheets of the local municipal utilities of all the systems. 
It is worth noting that the total plant value has increased from $10,081,469.16 
in 1913 to $91,184,586.56 in 1933, and the total assets from $11,907,826.86 to 
$135,703,252.64. The liabilities have not increased in the same proportion as 
the assets, rising from $10,468,351.79 to $49,920,753.88. The reasons for this 



282 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 

are the regular fulfilment of debt retirement schedules under serial debenture 
provisions or by maturity of sinking funds, and also the fact that much of the 
cost of the increasing plant value has been financed out of reserves and surplus 
without increasing the capital liabilities of the respective utilities. By this 
procedure the funds of the systems are used to best advantage. Examination 
of the results will also show that there is a steady decline in the percentage of 
net liabilities to total assets; being from 88.0 per cent in 1913 to 39.5 per cent 
in 1933. The equities in the Hydro-Electric Power Commission's systems 
automatically acquired through the inclusion of sinking funds as part of the 
cost of power are not taken into account in arriving at these percentages. 

The second financial statement presents consolidated operating reports 
for each year since "Hydro" service was inaugurated and combines the results 
from the local municipal utilities of all the systems. After providing for every 
cost of operation and fixed charges, including the standard provision for 
depreciation, the combined operating reports show a net shortage of $627,011.33 
for 1933. 

The five statements, "A" to "E," following the two consolidated reports 
show the financial status of each municipal utility and the results of operations, 
giving classified information respecting revenue, operating costs, number of 
consumers and consumption, cost of power to municipalities, power and lighting 
rates charged to consumers, etc. In the statements "A" and "B," the munici- 
palities are arranged alphabetically under each system; in statement "D" the 
municipalities are arranged in three groups — cities, towns and small munici- 
palities; in statements "C" and "E" all municipalities are arranged alphabetically. 

Statement "A" presents the balance sheet of each electrical utility. The 
plant values are portrayed under the general subdivisions specified in the 
standard accounting system and the other items on the positive side of the 
ledger which are included in total assets are, by their nomenclature, self- 
explanatory with the exception, perhaps, of the item entitled "equity in H.E.P.C. 
systems." This represents the amount of accumulated sinking fund credited 
to the municipal utilities through the medium of "power cost" and accrued 
interest, toward the ultimate retirement of the capital invested by the Hydro- 
Electric Power Commission of Ontario on their behalf. The total accumulation 
by these municipalities at the end of 1933 is shown in the consolidated balance 
sheet to be $26,045,679.00. 

In conformity with a policy of service at cost to the customer, refunds by 
cash or credit were made during the year in many municipalities from surplus 
funds accrued to the credit of municipal services, such as street lighting, water 
works, sewage disposal, etc., and to individual customers. The amounts of the 
accumulated surpluses rebated equalled, in different municipalities, from one- 
twelfth to one-third of the previous year's revenue. The total thus returned to 
customers during the year 1933 amounted in round figures to $240,000.00. 

In each case the balance sheets are complete and final, and include the 
adjustments between the estimated and actual costs of power to the municipality. 

The reserves for depreciation, and the acquired equity in the Hydro- Electric 
Power Commission's systems, are listed individually and totalled; and under 
the heading "surplus" are included not only the free operating surplus 
but the accumulation of sinking fund applicable to debenture debt and also 
the amount of debentures alreadv retired out of revenue. 



1934 HYDRO-ELECTRIC POWER COMMISSION 283 

The depreciation reserve now amounts to 20.18 per cent of the total de- 
preciable plant, while the depreciation reserve and surplus combined have 
already reached the sum of $57,688,737.92, approximately 63.26 per cent of 
the total plant cost. 

Statement "B" shows detailed operating reports for each municipal 
electrical utility. It gives annual revenues from the various classes of consumers; 
the items of expenditure which make up the total annual expenditure and the 
sums set aside for depreciation. The population served by each local utility, 
and the number of consumers of each class are also shown. 

The item "power purchased" in this statement includes the debit or credit 
balances ascertained by the annual adjustment of the cost of power supplied 
to the municipalities by the Commission. 

Of the 282 municipal electric utilities included in this statement, 171 
received from consumers revenue sufficient to meet in full all operating expenses, 
interest, debt retirement instalments, and standard depreciation reserve allo- 
cation and to yield an aggregate net surplus of $306,522.71 for the year; 75 were 
able to defray out of revenue all such charges except a portion of the standard 
depreciation allocation aggregating $613,701.11; in the case of 36 utilities the 
revenue was less than the total of operating expenses, interest and debt retirement 
instalments by $95,258.10. 

Statement "C" shows the installation of street lights in each municipality 
together with the rates approved by this Commission, the revenue for 1933, 
and the cost per capita in each municipality. 

Statement "D" presents statistics relating to the supply of electrical 
energy to consumers in Ontario municipalities served by the Commission. It 
shows the revenue, kilowatt-hour consumption, number of consumers, average 
monthly consumption, average monthly bill and the net average cost per 
kilowatt-hour both for domestic and for commercial light service in each munici- 
pality. For power service this statement shows the revenue, the number of 
consumers and the average horsepower supplied by the municipal utility.* For 
further reference to this informative statement, consult the special introduction 
to it on page 406. 

Statement "E" presents the cost per horsepower of the power provided 
for and delivered to the municipalities by the Commission, and the local rates 
to consumers in force in the respective municipalities, during the year 1933, for 
domestic service, for commercial light service and for power service. 



*The statistics include retail power only. Wholesale industrial power as supplied by the 
Commission direct, is reported in Section IX. 

Note: In 1933-34, the Ontario Municipal Electric Association requested information 
respecting the remuneration paid certain members of the staff, and in this connection it was 
stated that for this year the information would be placed in the Municipal section of the Annual 
Report. 

The Commission retains out of the salary of its employees an amount to provide for Pension 
and Insurance. After such deduction the present (1933-1934) yearly remuneration to the following 
members of the staff as requested is:— F. A. Gaby, $29,070.00; I. B. Lucas, $10,895.04; W. W. 
Pope, $8,707.44; T. H. Hogg, $13,520.04; E. T. J. Brandon, $12,470.04; R. T. Jefferv, $10,895.04; 
W. R. Robertson, $6,695.04; H. C. Don Carlos, $10,895.04; W. G. Pierdon, $10,895.04; A. E. 
Davison, $5,532.72; W. P. Dobson, $6,170.04; B. O. Salter, $5,090.04; A. V. Trimble, $10,695.00; 
A. V. White. $9,142.08. The present remuneration of the Chairman is $13,175.04 and Com- 
missioners $7,975.08. 



284 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



CONSOLIDATED 



Year 


1913 


1914 


1915 






Number of municipalities included 


45 


69 


99 


Assets 

Lands and buildings 

Substation equipment 

Distribution system — overhead 

Distribution system — underground 

Line transformers 

Meters 

Street lighting equipment — regular 

Street lighting equipment — ornamental. . 
Miscellaneous construction expenses. . . . 
Steam or hydraulic plant 


$ c. 

626,707.34 

1,090,875.69 

2,690,834.74 

644,514.24 

615,546.20 

840,606.64 

900,614.80 

62,765.34 

866,551.89 

1,401,175.28 

341,277.00 


$ c. 

791,732.20 

1,476,087.84 

3,422,763.93 

807,153.53 

787,613.52 

1,172,475.11 

1,071,255.37 

270,386.55 

2,062,035.90 

420,108.33 

619,513.12 


$ c. 

873,838.18 
1,582,062.56 
4,234,626.05 

928,420.77 

981,754.70 
1,418,165.08 
1,309,628.49 

197,644.82 
1,701,182.66 

461,651.60 


Old plant 


1,184,372.86 






Total plant 


10,081,469.16 
450,887.97 


12,901,125.40 
422,350.12 


14,873,347.77 


Bank and cash balance 


284,653.96 


Securities and investments 




Accounts receivable 

Inventories 


344,487.95 
540,274.58 
431,747.27 


561,873.08 
615,226.76 
625,217.03 


602,920.69 
726,556.76 


Sinking fund on local debentures 

Equity in H-E-P.C. systems 


868,983.78 


Other assets 


58,959.93 


123,410.97 


326,801.11 






Total assets 


11,907,826.86 


15,249,203.36 


17,683,264.07 






Liabilities 

Debenture balance 

Accounts payable 

Bank overdraft 


8,711,308.37 

1,553,711.45 

160,919.16 

42,412.81 


10,678,078.36 

1,682,150.29 

228,622.50 

113,838.66 


11,831,811 .03 

2,040,038.01 
292,106.44 


Other liabilities 


37,388.31 


Total liabilities 


10,468,351.79 


12,702,689.81 


14,201,343.79 






Reserves 
For equity in H-E.P.C. systems 








For depreciation 


478,145.88 


850,618.07 


1,337,739.73 


Other reserves. . 












Total reserves 


478,145.88 


850,618.07 


1,337 739.73 






Surplus 
Debentures paid 


202,751.26 
431,747.27 
326,830.66 


320,129.10 
625,217.03 
750,549.35 


394,466.22 


Local sinking fund 


868,983.78 


Operating surplus 


880,730.55 


Total surplus 


961,329.19 


1,695,895.48 


2,144,180.55 


Total liabilities, reserves and surplus. . . 


11,907.826.86 


15,249,203.36 


17,683,264.07 


Percentage of net debt to total assets. . . 


88.0 


88.3 


80.3 



Note. — In computing the percentage of net debt to total assets the sinking fund on local 
debentures and equity in H-E.P.C. systems are excluded from assets, and total liabilities are 
reduced by amount of local sinking fund. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



285 



BALANCE SHEET 



1916 


1917 


1918 


1919 


1920 


1921 


128 


143 


166 


191 


195 


215 


$ c. 

1,335,936.33 

1,934,626.12 

4,832,353.27 

1,095,709.62 

1,179,132.07 

1,711,299.49 

1,251,057.13 

306,388.95 

2,059,263.42 

864,500.01 

759,748.66 


$ c. 

1,546,241.41 

2,471,293.82 

6,090,073.42 

1,157,059.90 

1,483,839.44 

1,999,095.48 

1,237,734.69 

361,975.74 

2,184,015.84 

896,753.20 

649,852.51 


$ c. 
1,859,888.69 
2,820,488.70 
6,627,237.39 
1,216,288.59 
1,772,691.35 
2,238,143.70 
1,200,625.65 

531,502.61 
2,395,096.50 

214,575.75 
1,476,413.00 


$ c. 

1,995,545.83 

2,915,125.56 

7,445,8z0.31 

1,206,296.88 

2,073,113.45 

2,587,566.32 

1,206,638.71 

546,497.68 

2,530,101.08 

986,200.57 

805,959.89 


$ c 

2,175,568.24 

3,231,050.80 

8,579,881 .49 

1,313,369.29 

2,560,581.59 

3,053,135.20 

1,269,006.98 

557,678.13 

2,697,636.12 

757,194.47 

864,298.39 


$ c. 

3,230,985.63 

5,403,689.90 

8,397,361.48 

1,401,135.97 

3,077,649.83 

3,552,076.79 

1,335,997.13 

610,586.70 

3,030,134.16 

704,848.46 

912,388.55 


17,330,015.07 
1,061,029.90 


20,077,935.45 
340,026.50 


22,352,951.93 
391,194.91 


24,298,866.28 

462,437.23 

627,076.53 

1,921,166.69 

1,032,569.75 

1,925,455.77 

369,071.89 

86,216.05 


27,059,400.70 

943,858.12 

341,855.88 

2,022,538.88 

1,400,671.89 

2,244,004.34 

577,584.06 

25,447.07 


31,656,854.60 

900,842.34 
477,678.69 


695,152.23 

764,504.59 

1,166,017 .73 


1,285,097.33 
1,261,398.36 
1,337,578.96 


1,124,018.44 

972,996.96 

1,663,298.05 


2,155,788.62 

1,504,596.28 

2,541,718.35 

795,570.51 


342,215.87 


125,240.05 


444,787.63 


78,929.84 


21,358,935.39 


24,427,276.65 


26,949,247.92 


30,722,860.19 


34,615,360.94 


40,111,979.23 


15,058,641.57 
969,187.75 
178,413.26 
491,874.90 


15,593,773.61 

1,537,669.11 

886,177.94 

429,104.20 


17,209,217.70 

1,007,727.79 

576,816.49 

350,013.21 


18,133,462.44 

1,420,926.66 

403,235.57 

670,271.90 


19,268,072.04 

1,840,137.54 

514,671.99 

642,293.65 


21,619,220.99 

1,887,567.93 

989,099.98 

938,368.84 


16,698,117.48 


18,446,724.86 


19,143,775.19 


20,627,896.57 


22,265,175.22 


25,434,257.74 








373,871.89 
3,750,162.28 


577,584.06 
4,788,645.03 


800,249.05 


1,843,804.68 


2,463,723.83 


3,133,550.17 


5,491,858.93 














1,843,804.68 


2,463,723.83 


3,133,550.17 


4,124,034.17 


5,366,229.09 


6,292,107.98 


549,778.59 
1,165,785.94 
1,101,448.70 


694,797.90 
1,340,615.38 
1,481,414.68 


920,076.56 
1,662,602.69 
2,089,243.31 


1,328,657.68 
1,754,020.37 
2,888,251.40 


1,440,156.52 
2,246,474.47 
3,297,325.64 


1,860,079.53 
2,541,718.35 
3,983,815.63 


2,817,013.23 


3,516,827.96 


4,671,922.56 


5,970,929.45 


6,983,956.63 


8,385,613.51 


21,358,935.39 


24,427,276.65 


26,949,247.92 


30,722,860.19 


34,615,360.94 


40,111,979.23 


78.4 


75.5 


71.0 


67.9 


65.4 


64.7 



286 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



CONSOLIDATED 



Ykar 


1922 


1923 


1924 






Number of municipalities included 


226 


235 


248 


Assets 
Lands and buildings 


$ c. 
3,334,522.68 
5,046,857.98 
11,165,330.24 
1,598,053.02 
3,618,684.73 
4,033,689.52 
1,419,016.05 

666,084.50 
3,261,495.74 

565,158.54 
7,997,947.87 


$ c 
4,488,054.93 
6,015,919.75 
13,135,581.76 
1,959,120.41 
4,211,655.89 
4,548,933.73 
1,061.473.85 

708,431.22 
3,681,274.88 

566,619.86 
8,051,496.28 


$ c. 
4,561 648 92 


Substation equipment 


6,800,238 00 


Distribution system — overhead 

Distribution system — underground 

Line transformers 

Meters 

Street lighting equipment — regular 

Street lighting equipment — ornamental.. 
Miscellaneous construction expenses. . . . 

Steam or hydraulic plant 

Old plant 


14,182,190.33 
2,873,446.13 
4.456,669.02 
5,149,629.71 
1,134,491.77 
728,298.08 
4,168,262.21 
4,196,803.45 
5,587,420.31 






Total plant 


42,706,840.87 

1,164,336.24 
443,938.18 
3,874,317.14 
1,738,795.96 
3,416,231.45 
1,543,434.12 
238,940.13 


48,428,562.56 

1,276,140.06 
1,153,424.47 
3,198,769.34 
1,819,711.62 
3,896,261.28 
2,929,603.94 
190,071.63 


53,839,097.93 


Bank and cash balance 


1,748,912.34 


Securities and investments 


1,329,622.58 


Accounts receivable 


3,898,751.89 


Inventories 


1,745,628.16 


Sinking fund on local debentures 

Equity in H-E.P.C. systems 

Other assets 


4,520,723.06 

5,420,567.58 

250,292.77 






Total assets .... 


55,126,834.09 


62,892,544.90 


72,753,596.31 






Liabilities 
Debenture balance. . 


30,454,186.12 

3,699,292.52 

456,706.69 

586,203.02 


33,056,501.29 

3,708,781.76 

680,714.59 

1,517,828.47 


38,005,162.50 


Accounts payable 


3,117,224.08 


Bank overdraft 


162,100.71 


Other liabilities 


1,780,564.27 






Total liabilities 


35,196,388.35 


38,963,826.11 


43,065,051.56 






Reserves 

For equity in H-E.P.C. systems 

For depreciation 


1,543,434.12 
6,512,813.92 


2,929,603.94 
7,328,858.69 


5,420,567.58 
8,097,834.68 


Other reserves 












Total reserves 


8,056,248.04 


10,258,462.63 


13,518,402.26 






Surplus 
Debentures paid 


3,104,591.15 
3,416,231.45 
5,353,375.10 


2,852,038.38 
3,896,261.28 
6,921,956.50 


3,530,610.35 


Local sinking fund 


4,520,723.06 


Operating surplus 


8,118,809.08 






Total surplus 


11,874,197.70 


13,670,256.16 


16,170,142.49 






Total liabilities, reserves and surplus. . . 


55,126,834.09 


62,892,544.90 


72,753,596.31 


Percentage of net debt to total assets. . . 


63.3 


62.6 


61.4 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



287 



BALANCE SHEET— Continued 



1925 


1926 


1927 


1928 


1929 


1930 


247 




251 


252 


256 


260 


267 




$ 


c. 


$ 


c. 


$ 


c. 


$ 


c. 


$ 


(-. 


$ 


c. 


5,768,855 


09 


6,111,162 


54 


6,486,426 


89 


7,024,646. 


76 


7,469,451 


46 


7,936,974 


31 


8,543,166 


55 


9,505,501 


77 


15,088,905 


14 


16,866,186 


21 


18,102,792 


13 


19,485,056 


28 


16,837,535 


57 


18,654,240 


54 


16,689,462 


41 


17,688,050 


68 


18,108,016 


82 


19,220,326 


48 


3,388,837 


09 


3,689,569.95 


3,278,382 


58 


3,559,288 


16 


4,823,369 


60 


4,932,189 


05 


5,079,754 


23 


5,538,605 


24 


5,985,521 


37 


6,549,674 


64 


7,312,742 


17 


7,953,090 


23 


5,533,483 


92 


5,963,162 


51 


6,346,660 


59 


6,839,802 


90 


7,405,478 


91 


7,840,948 


07 


1,256,916 


53 


1,309,608 


30 


1,399,314 


06 


1,486,646 


24 


1,594,183 


25 


1,780,785 


67 


893,186 


48 


1,103,660 


23 


1,184,035 


82 


1,203,706 


65 


1,458,349 


64 


1,520,891 


01 


4,485,110 


96 


3,456,777 


71 


3,360,671 


09 


3,394,626 


92 


3,483,487 


78 


3,996,747 


77 


568,912 


49 


628,909 


57 


607,320 


00 


619,880 


93 


489,097 


57 


139,587 


28 


4,549,142 


46 


4,655,422 


59 


5,095,555 


90 


5,032,089 


26 


5,093,378 


75 


5,322,690 


14 


56,904,902 


27 


60,616,620 


95 


65,522,255 


85 


70,264,599 


35 


75,340,348 


08 


80,129,286 


29 


1,700,145 


30 


2,136,290 


79 


3,014,832 


48 


1,342,367 


07 


858,733 


68 


2,722,250 


12 


1,095,662 


92 


1,400,316.43 


1,696,237 


66 


1,837,140 


51 


2,001,088 


81 


1,909,439 


11 


3,417,558 


86 


3,508,817 


87 


3,715,770 


72 


4,097,446 


13 


4,683,201 


97 


4,481,006 


92 


1,711,504 


13 


1,397,667 


83 


1,412,729 


41 


1,220,186 


10 


1,365,033 


58 


1,242,994 


51 


5,202,451 


70 


5,599,675 


01 


6,398,909 


77 


7,071,273 


69 


7,753,613 


88 


8,396,255 


47 


7,551,588 


70 


8,046,868 


53 


10,143,205 


66 


12,326,097 


56 


14,754,865 


40 


17,346,372 


44 


137,280.05 


33,151 


81 


31,942 


45 


153,275 


04 


152,260 


86 


173,030 


05 


77,721,093 


93 


82,739,409 


22 


91,935,884 


Of) 


9,8312,385 


45 


106,909,146 


26 


116,400.634 


91 


37,919,225 


01 


39,602,533 


48 


42,891,361 


57 


42,597,175 


78 


42,930,127 


74 


45,091,808 


06 


3,139,067 


92 


3,118,684 


78 


2,988,621 


90 


3,074,634 


25 


3,132,145 


03 


3,001,186 


21 


226,147 


82 


163,725 


53 


252,362 


52 


253,143 


81 


412,056 


69 


405,663 


14 


1,075,914 


S3 


1,087,795 


08 


1,154,810 


24 


1,258,610 


23 


1,621,378 


17 


1,642,771 


59 


42,360,355 


58 


43,972,738 


87 


47,287,156 


23 


47,183,564 


07 


48,095,707 


63 


50,141,429 


00 


7,551,588 


70 


8,046,868 


53 


10,143,205 


66 


12,326,097 


56 


14,754,865 


40 


17,346,372 


44 


8,699,437 


68 


9,360,322 


27 


10,319,889 


05 


11,140,795 


68 


11,911,154 


49 


12,885,387 


51 


1,157,147 


20 


947,970 


23 


1,002,916 


69 


1,117,257 


63 


1,437,371 


26 


1,574,655 


74 


17,408,173 


58 


18,355,161 


03 


21,466,011 


40 


24,584,150 


87 


28,103,391 


15 


31,806,415 


69 


4,440,138 


34 


5,493,879 


S3 


6,648,767 


3S 


7,928,907 


61 


9,194,253 


59 


10,728,279 


.15 


5,202,451 


70 


5,599,675 


01 


6,398,909 


77 


7,071,273 


69 


7,962,121 


.20 


8,396,255 


.47 


8,309,974 


.73 


9,317,954.48 


10,135,039 


.22 


11,544,489 


21 


13,553,672 


.69 


15,328,255 


.60 


17,952,564 


77 


20,411,509 


32 


23,182,716 


.37 


26,544,670 


51 


30,710,047 


.48 


34,452,790 


22 


77,721,093 


93 


82,739,409 


22 


91,935,884 


00 


98,312,385 


45 


106,909,146 


.26 


116.400,634 


.91 


57.2 


55.5 


54.2 


50.8 


47.8 


46.0 



288 



TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 



CONSOLIDATED BALANCE SHEET— Concluded 



Yeak 


1931 


1932 


1933 






Number of municipalities included 


275 


280 


282 


Assets 
Lands and buildings 


$ c. 

8,407,664.48 

21,013,956.74 

19,918,355.76 

5,361,627.24 

8,649,875.07 

8,106,202.88 

2,205,613.18 

1,456,742.91 

3,827,132.05 

458,374.05 

7,146,437.96 


$ c. 

9,503,743.78 

22,288,781.68 

20,866,767.32 

5,820,056.75 

9,392,662.62 

8,403,251.67 

2,257,618.20 

1,545,354.93 

4,120.926.11 

498,231.69 

4,989,654.97 

200,000.00 


$ c 

10,186,471.28 

22,306,800.94 

21,152,681.20 

5,945,225.61 

9 478 605 14 


Substation equipment 


Distribution system — overhead 

Distribution system — underground 




8,514,165.03 
2,381,599.40 
1,458,443.68 
4,040,859.74 
502,978.62 
5,016,755.92 


Street lighting equipment — regular 

Street lighting equipment — ornamental.. 
Miscellaneous construction expenses. . . . 

Steam or hydraulic plant 

Old plant 


Other plants not distributed . 


200 000 00 








Total plant 


86,551,982.32 

2,738,319.67 
1,999,846.42 
3,957,972.78 
1,276,531.01 
8,735,050.84 
20,103.275.76 
174,879.28 


89,887,049.72 

3,185,442.00 
2,059,325.10 
3,683,059.42 
1,232,209.52 
9,099,210.61 
23,066,129.81 
163,637.79 


91,184,586.56 


Bank and cash balance 


1,696,489.24 


Securities and investments 


2,163,785.20 


Accounts receivable 


3,746,910.92 




1,226,043.30 


Sinking fund on local debentures 

Equity in H-E.P.C. systems 

Other assets 


9,386,176.58 

26,045,679.00 

253,581.84 






Total assets 


125,537,858.08 


132,376,063.97 


135,703,252.64 






Liabilities 
Debenture balance 


44,594,400.03 

5,382,306.13 

312,575.54 

1,909,986.13 


45,133,305.97 

3,512,724.58 

298,910.20 

3,740,376.11 


42,606,145.29 


Accounts payable 


3,320,485.45 


Bank overdraft 


206,398.00 


Other liabilities 


3,787,725.14 






Total liabilities 


52,199,267.83 


52,685,316.86 


49,920,753.88 






Reserves 

For equity in H-E.P.C. systems 

For depreciation 


20,103,275.76 

13,748,049.68 

1,693,129.83 


23,066,129.81 

14,902,177.02 

1,902,308.64 


26,045,679.00 
16,075,959.28 


Other reserves 


2,048,081.84 






Total reserves 


35,544,455.27 


39,870,615.47 


44,169,720.12 






Surplus 
Debentures paid 


13,150,040.37 

8,735,050.84 

15,909,043.77 


15,244,778.28 

9,099,210.61 

15,476,142.75 


17,651,367.71 


Local sinking fund 


9,386,176.58 


Operating surplus 


14,575,234.35 






Total surplus 


37,794,134.98 


39,820,131.64 


41,612,778.64 






Total liabilities, reserves and surplus. . . 


125,537,858.08 


132,376,063.97 


135,703,252.64 


Percentage of net debt to total assets. . . 


44.1 


43.4 


39.5 



Note. — In computing the percentage of net debt to total assets the sinking fund on local 
debentures and equity in H-E.P.C. systems are excluded from assets, and total liabilities are 
reduced by the amount of local sinking fund. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



289 



CONSOLIDATED OPERATING REPORT 



Year 


1912 


1913 


1914 


1915 






Number of municipalities included 


28 


45 


69 


99 


Earnings 
Domestic service 


$ c. 


$ c. 
572,154.38 
525,438.16 
905,378.17 


$ c 

789,130.81 

673,803.92 

1,214,829.31 


$ c 
944,271.08 


Commercial light service . . .- 




720,209.26 


Commercial power service 




1,501,797.78 


Municipal power 






Street lighting 




560,925.56 


698,409.71. 


835,970.87 


Rural service 






Miscellaneous 




53,543.24 


57,482.41 


68,046.29 








Total earnings 


1,617,674.00 


2,617,439.51 


3,433,656.16 


4,070,295.28 






Expenses 
Power purchased 




789,632.87 
78,394.81 
18,698.46 

104,114.51 

8,547.61 

5,222.19 

53,108.38 

84,903.76 
72,303.51 
77,351.76 

154,932.69 
65,423.64 

528,549.21 

* 


1,045,752.65 
97,658.90 
31,790.99 

130,998.65 

11,764.32 

9,536.07 

65,192.23 

113,047.80 
86,683.02 

103,560.71 

230,899.75 
89,350.91 

662,092.34 

* 


1,484,666.00 


Substation operation 




107,607.31 


Substation maintenance 




25,935.56 


Distribution system, operation and 
maintenance 




154,409.71 


Line transformer maintenance 




11,508.92 


Meter maintenance 




12,899.14 


Consumers' premises expenses 




47,494.26 


Street lighting, operation and main- 
tenance 




136,983.38 


Promotion of business 




74,402.55 


Billing and collecting 




131,541.27 


General office, salaries and expenses 
Undistributed expense 




236,777 86 




129,209.15 


Interest 




817,978.89 


Sinking fund and principal pay- 
ments on debentures 




* 








Total expenses 


1,377,168.00 


2,041,183.40 


2,678,328.34 


3,371,414.00 






Surplus 


240,506.00 
124,992.47 


576,256.11 
262,675.24 


755,327.82 
357,883.31 


698,881.28 


Depreciation charge 


414,506.99 


Surplus less deprecation 


115,513.53 


313,580.87 


397,444.51 


284,374.29 



*Debenture payments included in "Interest." 



290 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



CONSOLIDATED 



Year 


1916 


1917 


1918 






Number of municipalities included 


128 


143 


166 


Earnings 
Domestic service 


$ c. 
1,172,878.96 

812,130.78 
1,921,152.31 


$ c. 

1,417,460.31 

899,023.72 

2,665,280.65 


$ c. 

1,632,272.12 

968,399.42 

3,417,248.37 


Commercial light service 


Commercial power service 




Street lighting 


930,057.48 


967,495.10 


902,875.55 


Rural service 


Miscellaneous 


147,381.50 


120,805.39 


161,243.70 




Total earnings 


4,983,601.03 


6,070,065.17 


7,082.039.16 




Expenses 
Power purchased 


1,959,446.83 

153,761.08 

46,131.53 

154,247.17 
14,528.17 
24,218.48 
52,602.01 

145,471.50 

154,508.58 

306,709.35 

97,333.97 

* 


2,573,879.37 

203,091.20 

42,129.04 

169,326.24 
25,328.95 
44,461.55 
61,765.14 

157,857.73 

188,083.84 
349,932.05 
102,938.80 

* 


2,807,769.33 

238,257.34 

60,805.92 

223,347.81 
30,488.83 
63,155.56 
65,149.59 

196,157.18 

208,660.76 
421,680.15 
117,474 07 


Substation operation 


Substation maintenance 


Distribution system, operation and main- 
tenance 


Line transformer maintenance 


Meter maintenance 


Consumers' premises expenses 


Street lighting, operation and mainten- 
ance 


Promotion of business 


Billing and collecting 


General office, salaries and expenses .... 
Undistributed expense 




* 


Sinking fund and principal payments on 






Total expenses 


4,140,065.51 


5,077,491.08 


5,736,334 85 






Surplus 


843,535.52 
486,141.80 


992,574.09 
607,296.29 


1,345,704.31 


Depreciation charge 


718,162.30 






Surplus less depreciation 


357,393.72 


385,277.80 


627,542.01 







*Debenture payments included in "Interest." 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



291 



OPERATING REPORT— Continued 



1919 


1920 


1921 


1922 


1923 


1924 


181 


186 


205 


214 


224 


241 


$ c. 
1,991,632.31 
1,175,143.56 
3,443,107.13 


$ c. 

2,546,345.30 

1,512,854.63 

3,752,188.22 

532,279.09 

1,005,535.11 

168,919.95 

189,778.63 


$ c 

3,149,080.03 

1,851,501.76 

3,895,437.46 

654,531.01 

1,060,357.77 

145,566.57 

225,467.70 


$ c. 

3,786,608.23 

2,158,306.34 

4,383,912.97 

973,263.38 

1,160,446.81 

105,877.09 

187,689.39 


$ c. 
5,166,452.24 
3,260,772.50 
5,927,666.37 
1,161,598.60 
1,269,604.48 
116,639.06 
316,311.21 


$ c. 
5,993,231.07 
3,566,227.22 
6,222,865.88 
1,352,966.47 


988,900.95 


1,356,668.97 
75,100.24 


228,270.65 


231,663.58 


7,827,054.60 


9,707,900.93 


10,981,942.30 


12,756,104.21 


17,219,044.46 


18,798,723.43 


3,284,490.68 

217,638.89 

81,853.63 

286,310.76 
42,509.12 
78,726.64 
84,301.24 

215,963.86 

74,789.22 

236,504.75 

452,131.22 

190,690.09 

1,285,571.51 

* 


4,216,667.87 
285,407.35 
102,050.81 

344,551.57 

46,323.09 

123,701.18 

116,283.52 

236,930.79 
78,294.85 
295,942.88 
559,695.29 
256,400.33 
1,431,807.16 

* 


4,876,650.31 
314,838.35 
104,798.01 

487,918.33 

65,088.46 

116,722.97 

134,854.92 

297,481.52 
101,804.46 
321,685.71 
656,268.11 
308,874.42 
998,611.47 

532,183.96 


6,636,853.37 
315,443.70 
100,763.67 

519,252.16 

52,932.26 

107,806.88 

143,388.88 

297,363.86 
129,932.63 
338,153.50 
605,852.50 
385,895.03 
1,074,657.44 

635,469.90 


8,699,026.67 
474,442.13 
133,815.53 

636,477.41 

75,920.10 

139,104.81 

218,682.02 

299,579.08 
184,371.00 
444,306.92 
937,463.47 
359,206.91 
1,615,205.16 

990,907.14 


9,669,789.40 
430,056.09 
202,050.04 

648,700.62 

82,936.50 

141,231.23 

237,316.20 

269,973.30 
202,060.74 
490,273.30 
889,907.66 
494,078.50 
1,779,991.26 

1,122,798.87 


6,531,481.61 


8,094,056.69 


9,317,781.00 


11,343,765.78 


15,208,508.35 


16,661,163.71 


1,295,572.99 
814,219.37 


1,613,844.24 
902,028.75 


1,664,161.30 
1,044,434.85 


1,412,338.43 
715,814.24 


2,010,536.11 
916,782.75 


2,137,559.72 
973,649.62 


481,353.62 


711,815.49 


619,726.45 


696,524.19 


1,093,753.36 


1,163,910.10 



292 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



CONSOLIDATED 



Year 


1925 


1926 


1927 






Number of municipalities included 


242 


248 


251 


Earnings 
Domestic service 


$ c. 
6,439,159.86 
3,866,292.79 
6,568,854.77 
1,923,093.09 
1,415,382.22 
37,975.18 
286,451.08 


$ c. 
7,372,602.62 
4,187,899.19 
6,789,217.54 
1,922,512.34 
1,457,686.21 
37,810.73 
471,134.15 


$ c. 
8,189,866.89 


Commercial light service 


4,626,815.51 


Commercial power service 


7,342,173.20 


Municipal power 


1,913,502.88 


Street lighting 


1,489,242.37 


Rural service 


13,765.72 


Miscellaneous 


581,913.04 






Total earnings 


20,537,208.99 


22,238,862.78 


24,157,279.61 






Expenses 
Power purchased 


11,063,123.34 
417,921.71 
207,497.63 

686,344.54 

75,473.28 

156,909.55 

252,808.47 

275,316.60 
217,102.24 
521,134.01 
891,640.29 
520,584.58 


12,185,669.10 
450,416.84 
286,520.37 

795,514.70 

74,876.11 

189,603.70 

275,020.62 

295,869.37 
234,696.74 
557,271.54 
786,742.60 
460,288.30 


13,505,583.77 
430,211 76 


Substation operation 


Substation maintenance. 


275,148 86 


Distribution system, operation and main- 
ance 


758,747.10 


Line transformer maintenance 


94,706.38 


Meter maintenance 


214,813.87 


Consumers' premises expenses 


285,352.68 


Street lighting, operation and mainten- 
ance 


318,395.79 


Promotion of business 


220,687.60 


Billing and collecting 


605,627.58 


General office, salaries and expenses . . 
Undistributed expense 


824,868.90 
531,003.80 


Truck operation and maintenance 




Interest 


1,889,810.95 
1,294,027.29 


1,985,233.73 
1,347,511.92 


2,063,698.00 


Sinking fund and principal pavments on 
debentures 


1,505,626.31 






Total expenses 


18,469,694.48 


19,925,235.64 


21,634,472.40 






Surplus 


2,067,514.51 
1,068,880.42 


2,313,627.14 
1,146,273.05 


2,522,807.21 


Depreciation charge 


1,249,711.65 






Surplus less depreciation 


998,634.09 


1,167,354.09 


1,273,095.56 







1934 



HYDRO-ELECTRIC POWER COMMISSION 



293 



OPERATING REPORT— Concluded 



1928 


1929 


1930 


1931 


1932 


1933 


255 


259 


267 


275 


280 


282 


$ c. 
8,925,050.56 
5,182,723.32 
8,298,669.44 
1,921,300.97 
1,534,476.98 
48,451.90* 
465,791.92 


$ c 
9,873,681.57 
5,697,766.06 
9,376,158.74 
2,086,444.24 
1,598,262.43 
51,590.54* 
522,780.95 


$ c. 

10,542,903.89 

5,961,383.23 

9,340,653.28 

2,111,482.38 

1,674,528.03 

28,954.60* 

581,914.78 


$ c. 

10,972,952.10 

6,230,475.89 

9,456,224.97 

1,967,118.54 

1,746,855.24 

29,446.38* 

511,139.80 


$ c. 

11,447,307.85 

6,243,794.01 

9,356,693.88 

1,859,585.35 

1,783,972.46 

11,069.27* 

513,787.30 


$ c. 

11,429,101 13 

6,013,025.96 

9,080,522.07 

1,826,872 07 

1,779,582.48 

*12,812.74 

485,925.43 


26,376,465.09 


29,206,684.53 


30,241,820.19 


30,914,212.92 


31,216,210.12 


30,627,841.88 


14,688,570.08 
420,512.48 
247,647.88 

736,159.85 

88,676.18 

218,530.96 

291,333.03 

329,597.16 
249,842.01 
638,797.02 
844,578.55 
542,755.34 


16,379,162.88 
461,270.27 
274,275.56 

907,817.04 

93,608.14 

242,126.27 

314,495.03 

359,373.40 
250,844.. 28 
695,729.42 
904,025.64 
502,206.06 
110,630.62 
2,152,695.49 

1,687,201.64 


17,323,077.97 
479,502.48 
320,716.48 

991,972.86 

96,746.35 

278,379.43 

317,902.45 

372,211.17 
249,070.05 
745,159.02 
907,226.89 
523,862.96 
112,029.82 
2,220,214.45 

1,828,061.62 


18,085,166.51 
487,484.17 
303,536.11 

1,015,256.14 

93,463.24 

284,633.88 

363,078.47 

368,119.49 
255,956.03 
792,983.99 
923,676.84 
520,893.10 
107,918.93 
2,328,094.32 

2,061,718.79 


19,109,036.25 
503,351.82 
300,186.15 

969,750.61 

95,485.55 

300,104.85 

368,208.73 

360,709.76 
266,760.84 
818,721.33 
960,558.88 
436,692.96 
112,059.90 
2,532,940.93 

2,244,367.86 


19,330,861.58 
484,764.57 
288,583.29 

895,350.99 

82,321.32 

283,115.98 

361,499.20 

353,082.15 
259,936.42 
817,660.03 
908,517.79 
349,101.36 
105,452.68 


2,111,049.49 
1,601,711.32 


2,426,286.35 
2,319,319.09 


23,009,761.35 


25,335,461.74 


26,766,134.00 


27,991,980.01 


29,378,936.42 


31,254,853.21 


3,366,703.74 
1,350,252.16 


3,871,222.79 
1,469,846.83 


3,475,686.19 
1,574,991.68 


2,922,232.91 
1,775,330.69 


1,837,273.70 
1,920,896.22 


1,361,989.08 
1,989,000.41 


2,016,451.58 


2,401,375.96 


1,900,694.51 


1,146,902.22 


83,622.52 

(loss) 


627,011.33 

(loss) 



* Profits from the sale of merchandise. Rural service now given in "Rural Power Districts.' 
Consult Section IX. 



294 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



NIAGARA 
SYSTEM 



Municipality 


Acton 
1,895 


Agincourt 
P.V. 


Ailsa 

Craig 

464 


Alvinston 
690 


Amherst- 


Population 


burg 
3,086 






Assets 

Lands and buildings 


$ c. 

1,545.45 

1,847.39 

23,482.38 


$ c. 


$ c. 


$ c. 
133.56 


$ c. 


Substation equipment 






932 00 


Distribution system — overhead. . . 
Distribution system- — underground 
Line transformers 


8,481.56 


8,174.03 


14,008.12 


33,614.83 


11,302.83 

10,472.15 

1,880.04 


3,686.18 

2,479.55 

767.19 


1,946.95 

2,571.67 

404.09 


3,024.48 
2,972.37 
1,090.62 


15,917.83 


Meters 


15,219.85 


Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


812.44 
5,598.72 


2,620.49 


104.85 


492.36 


791.52 


1,600.27 


Old plant . 


3,481.50 






773.85 




Other plants not distributed 




















Total plant 


56,632.23 

3,137.53 

1,500.00 

592.60 

818.04 


15,519.33 

2,511.49 

1,000.00 

1,139.69 

2.04 


13,589.10 

3,205.11 

5,000.00 

39.15 


22,794.52 

282.09 

2,000.00 

456.09 


73,695.94 
7,440.26 


Bank and cash balance 


Securities and investments 

Accounts receivable 


1,898.30 
2,437.20 


Inventories 




Sinking fund on local debentures. . 








Equity in H-E.P.C. systems 

Other assets 


34,576.27 
589.02 


5,182.99 


9,541.72 


9,622.20 


27,567.04 
3,140.64 












Total assets 


97,845.69 


25,355.54 


31,375.08 


35,154.90 
3,814.05 


116,179.38 


Deficit 














Total 


97,845.69 


25,355.54 


31,375.08 


38,968.95 


116,179.38 






Liabilities 

Debenture balance 




3,433.73 
583.80 




12,450.39 
916.90 


25,176.10 


Accounts payable 


13.13 


200.65 




Bank overdraft 




Other liabilities 


542.09 




92.00 




7,144.27 






Total liabilities 


555.22 


4,017.53 


292.65 


13,367.29 


32,320.37 






Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


34,576.27 
9,654.09 


5,182.99 
1,530.63 


9,541.72 
5,174.27 


9,622.20 
4,900.61 


27,567.04 
14,021.84 


Other reserves 
















Total reserves 


44,230.36 


6,713.62 


14,715.99 


14,522.81 


41,588.88 






Surplus 

Debentures paid 


14,500.00 


4,638.92 


6,883.38 


11,078.85 


6,877.50 


Local sinking fund 




Operating surplus 


38,560.11 


9,985.47 


9,483.06 




35,392.63 








Total surplus 


53,060.11 


14,624.39 


16,366.44 


11,078.85 


42,270.13 






Total liabilities, reserves and surplus 


97,845.69 


25,355.54 


31,375.08 


38,968.95 


116,179.38 


Percentage of net debt to total assets 


0.8 


19.9 


1.3 


52.4 


32.2 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



293 



'A v 



Hydro Municipalities as at December 31, 1933 



Ancaster 
Twp. 


Arkona 
416 


Aylmer 
1,989 


Ayr 

768 


Baden 
P.V. 


Beachville 
P.V. 


Belle 
River 

746 


Blenheim 
1,690 


$ c. 


$ c. 


$ c. 
9,019.23 


$ c. 
125.00 


$ c. 
660 . 64 


$ c. 
176.13 


$ c. 


$ c. 








909.64 


15,858.22 


9,559.67 


20,733.69 


12,440.57 


7,474.60 


13,922.72 


16,266.23 


25,681.74 


10,236.49 
4,202.68 
1,269.78 


1,976.44 

1,549.36 

671.60 


10,356.91 
9,591.53 
1,723.79 


3,850.56 

3,580.79 

628.42 


4,048.22 

2,872.74 

447.45 


3,550.21 

3,142.06 

423.23 


3,651.15 

3,683.98 

924.29 


8,123.02 
9,116.00 
3,367.96 
1,482.97 


324 93 


225.47 


1,130.33 


941.79 




602.04 


1,043.78 


1,128.43 










1,030.30 


6,719.17 


4,002.53 




































31,892.10 


15,012.84 
88.03 


59,274.65 

1,314.13 

12,000.00 

1,365.89 

60.62 


25,569.66 
57.93 


15,503.65 
3,831.00 


21,816.39 

522.43 

4,000.00 

722.31 


25,569.43 

3,631.25 

3,000.00 

744.16 


49,809.76 
4,343.02 






1,761.46 


176.18 


1,196.70 




692.65 






30.34 
















8,321.47 


2,948.25 
54.54 


22,779.10 


8,153.15 


19,259.17 


23,913.36 


5,164.20 


21,191.34 
















41,975.03 


18,279.84 
1,561.01 


96,794.39 


34,977.44 


38,593.82 


50,974.49 


38,109.04 


76,067.11 
















41,975.03 


19,840.85 


96,794.39 


34,977.44 


38,593.82 


50,974.49 


38,109.04 


76,067.11 


7,921.48 

425.70 


9,736.09 
2,410.16 


20,208.85 
99.83 


6,948.52 


2,102.21 
161.80 


2,286.51 


5,454.34 
158.04 


8,527.23 
1,789.88 


1,659.51 








145.32 




108.00 








86.00 


220.00 














10,152.01 


12,146.25 


20,416.68 


6,948.52 


2,264.01 


2,286.51 


5,698.38 


10,537.11 


8,321.47 
6.199.21 


2,948.25 
1,369.61 


22,779.10 

9,529.63 

300.00 


8,153.15 
3,696.68 


19,259.17 
1,759.67 


23,913.36 
4,793.88 


5,164.20 
4,685.02 
5,000.00 


21,191.34 
10,739.62 














14,520.68 


4,317.86 


32,608.73 


11,849.83 


21,018.84 


28,707.24 


14,849.22 


31,930.96 


2,868.10 


3,376.74 


18,493.07 


10,554.86 


2,897.79 


3,066.49 


3,045.66 


5,472.77 


14.434.24 




25,275.91 


5,624.23 


12,413.18 


16,914.25 


14,515.78 


28,126.27 








17,302.34 


3,376.74 


43,768.98 


16,179.09 


15,310.97 


19,980.74 


17,561.44 


33,599.04 


41,975.03 


19,840.85 


96,794.39 


34,977.44 


38,593.82 


50,974.49 


38,109.04 


76,067.11 


30.1 


79.2 


27.5 


25.9 


11.7 


8.4 


17.3 


16.9 



296 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Blyth 
602 


Bolton 
593 


Bothwell 
646 


Brampton 
5,413 


Brantford 


Population 


30,724 


Assets 

Lands and buildings 


$ c. 


$ c. 


$ c. 


$ c. 

5,081.32 

24,742.53 

50,295.58 


$ c. 
85,595.31 


Substation equipment 








162,884.45 


Distribution system — overhead. . . 
Distribution system — underground 
Line transformers 


11,261.08 


9,931.57 


6,027.41 


229,785.83 
6,000.00 


2,441.35 
1,945.31 
1,284.19 


4,296.34 

2,958.86 

856.19 


2,575.37 
2,819.97 
4,634.70 


28,005.83 

26,131.27 

2,645.94 


112,926.91 


Meters 


115,872.40 


Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


24,010.22 
41,476.69 


284.97 


1,050.06 


550.01 


18,405.35 


30,529.82 


Old plant . 


2,332.68 


1,554.60 








Other plants not distributed 






200,000.00 














Total plant 


19,549.58 
1,173.22 


20,647.62 
895.96 


16,607.46 

2,475.99 

11,000.00 

82.04 


155,307.82 

2,400.28 

5,648.78 

1,100.49 

223.66 


1,009,081.63 


Bank and cash balance 




Securities and investments 




Accounts receivable 


1,009.53 


704.36 

22.41 


23,077.31 


Inventories 


11,344.36 


Sinking fund on local debentures. . 






90,906.83 


Equity in H-E.P.C. systems 

Other assets 


4,935.50 


10,636.75 


11,113.15 


93,084.35 


473,680.24 
47,506.37 














Total assets 

Deficit 


26,667.83 


32,907.10 


41,278.64 


257,765.38 


1,655,596.74 














Total 


26,667.83 


32,907.10 


41,278.64 


257,765.38 


1,655,596.74 






Liabilities 

Debenture balance 

Accounts payable 


9,006.10 
100.31 


6,013.66 
52.00 


3,045.38 
226.32 


12,794.35 
1,842.74 


263,000.00 
6,587.33 


Bank overdraft 


11,241.61 


Other liabilities 


50.00 




1,161.22 




166,542.06 










Total liabilities 


9,156.41 


6,065.66 


4,432.92 


14,637.09 


447,371.00 






Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


4,935.50 

2,774.77 


10,636.75 
4,997.25 


11,113.15 
5,755.07 


93,084.35 

42,919.03 

100.00 


473,680.24 
203,667.20 


Other reserves 


86,000.00 












Total reserves 


7,710.27 


15,634.00 


16,868.22 


136,103.38 


763,347.44 






Surplus 

Debentures paid 


7,262.93 


6,486.34 


2,488.81 


56,256.29 


267,000.00 


Local sinking fund 


90,906.83 


Operating surplus 


2,538.22 


4,721.10 


17,488.69 


50,768.62 


86,971.47 






Total surplus 


9,801.15 


11,207.44 


19,977.50 


107,024.91 


444,878.30 






Total liabilities, reserves and surplus 


26,667.83 


32,907.10 


41,278.64 


257,765.38 


1,655,596.74 


Percentage of net debt to total assets 


42.2 


27.2 


11.4 


8.9 


33.5 



934 



HYDRO-ELECTRIC POWER COMMISSION 



297 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



Brantford 
Twp. 


Bridgeport 
P.V. 


Brigden 
P.V. 


Brussels 
770 


Burford 
P.V. 


Burgess- 
ville 
P.V. 


Caledonia 
1,400 


Campbell- 
ville 
P.V. 


$ c. 


$ c. 


$ c. 
101.03 


$ c. 


$ c. 
202.00 


$ c. 


$ c. 


$ c. 


1,192 71 












52,268.73 


9,516.09 


7,090.80 


13,562.61 


9,240.38 


3,490.03 


17,022.28 


2,978.42 


16,784.09 

11,884.39 

4,338.80 


3,833.06 
2,217.15 
1,602.69 


2,037.61 

2,238.85 

464.90 


2,395.35 
3,810.08 
1,574.74 


2,933.19 

3,374.95 

425.14 


1,390.44 
966.40 
261.02 


6,432.74 
6,232.50 
1,582.94 


718.23 
567.30 
258.56 


2,922.09 


563.56 


858.11 


1,572.29 


717.31 


457.22 


692.59 


45.82 






1,381.00 


2,827.50 






































89,390.81 
6,741.22 


17,732.55 
300.27 


14,172.30 
475.66 


25,742.57 
3,959.91 


16,892.97 

1,884.70 

4,000.00 

571.36 


6,565.11 
560.08 


31,963.05 

1,638.23 

2,000.00 

20.65 


4,568.33 

525.63 
1,000.00 


405 . 19 


241.36 


473.04 


838.83 
24.48 


107.09 


268.67 


3,326.87 














15,720.56 


2,607.10 


7,049.89 


6,968.52 


7,656.25 
25.00 


3,190.64 


12,346.64 


860.46 
















115,584 65 


20,881.28 


22,170.89 


37,534.31 


31,030.28 


10,422.92 


47,968.57 


7,223.09 


















115,584.65 


20,881.28 


22,170.89 


37,534.31 


31,030.28 


10,422.92 


47,968.57 


7,223.09 


23,408.79 
3,272.61 


11,914.39 
698.27 


902.89 


13,245.52 
1,847.51 


382.11 
4.60 


560.39 

220.22 


1,780.41 
701.06 


3,593.44 
33.14 








1,443.25 


40.00 






25.00 




















28,124.65 


12,652.66 


902.89 


15,093.03 


411.71 


780.61 


2,481.47 


3,626.58 


15,720 56 
17,690.56 


2,607.10 
4,458.60 


7,049.89 
3,072.84 


6,968.52 
4,010.41 


7,656.25 
4,050.20 


3,190.64 

2,229.03 

85.41 


12,346.64 
3,949.40 


860.46 
676.54 
















33,411.12 


7,065.70 


10,122.73 


10,978.93 


11,706.45 


5,505.08 


16,296.04 


1,537.00 


33,716.87 
3,326.87 


453.64 


7,097.11 


7,754.48 


8,617.89 


2,939.61 


2,843.59 


1,854.33 


17,005.14 


709.28 


4,048.16 


3,707.87 


10,294.23 


1,197.62 


26,347.47 


205.18 


54,048.88 


1,162.92 


11,145.27 


11,462.35 


18,912.12 


4,137.23 


29,191.06 


2,059.51 


115,584.65 


20,881.28 


22,170.89 


37,534.31 


31,030.28 


10,422.92 


47,968.57 


7,223.09 


25.6 


69.2 


5.9 


49.4 


1.7 


10.8 


6.9 


57.0 



298 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Cayuga 
705 


Chatham 
16,223 


Chippawa 
1,073 


Clifford 
454 


Clinton 


Population 


1,842 






Assets 

Lands and buildings 


$ c. 


$ c. 
46,055.45 
116,587.41 
161,316.09 
79,554.42 
86,934.79 
67,774.93 
18,777.35 
35,426.10 
33,016.43 


$ c. 
631.50 


$ c. 


$ c. 
8,760.82 


Substation equipment 






7,544.43 


Distribution system — overhead . . . 
Distribution system — underground 
Line transformers 


14,080.88 


19,123.86 


7,451.37 


22,257.65 


3,162.29 

2,704.35 

942.83 


6,107.56 
4,702.80 
1,877.81 


1,161.99 

2,195.08 

687.42 


7,787.65 


Meters 


9,334.88 


Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


1,297.67 


474.44 


1,139.19 


37.44 


3,846.29 


Old plant 




42,752.31 






10,658.09 


Other plants not distributed 






















Total plant 


21,364.79 
2,141.86 


688,195.28 
17,934.82 


33,582.72 
421.83 


11,533.30 
400.44 


71,487.48 


Bank and cash balance 


1,991.97 


Securities and investments 


3,000.00 


Accounts receivable 

Inventories 


389.17 
131.34 


18,793.38 
3,703.83 


253.38 


131.53 
20.40 


1,276.61 
2,230.83 


Sinking fund on local debentures. . 




32,589.70 


Equity in H-E.P.C. systems 

Other assets .... 


4,608.67 


222,270.09 
3,604.51 


9,683.44 
194.56 


3,400.81 


26,385.91 










Total assets 


28,635.83 


954,501.91 


44,135.93 


15,486.48 


138,962.50 


Deficit 
















Total 


28,635.83 


954,501.91 


44,135.93 


15,486.48 


138,962.50 






Liabilities 

Debenture balance 

Accounts payable 


13,543.57 
851.67 


245,238.03 
23,289.92 


6,422.39 
32.01 


6,756.82 
373.14 


44,500.00 
495.93 


Bank overdraft .... 




Other liabilities 


35.00 


39,030.61 


190.00 




175.81 








Total liabilities 


14,430.24 


307,558.56 


6,644.40 


7,129.96 


45,171.74 


Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


4,608.67 
3,035.70 


222,270.09 

108,582.98 

4,974.96 


9,683.44 
6,469.01 


3,400.81 
1,657.34 


26,385.91 
20,000.45 


Other reserves. 


670.39 












Total reserves 


7,644.37 


335,828.03 


16,152.45 


5,058.15 


47,056.75 






Debentures paid 


6,456.43 


124,761.97 


6,927.61 


1,243.18 




Local sinking fund 


32,589.70 


Operating surplus 


104.79 


186,353.35 


14,411.47 


2,055.19 


14,144.31 






Total surplus 


6,561.22 


311,115.32 


21,339.08 


3,298.37 


46,734.01 






Total liabilities, reserves and surplus 


28,635.83 


954,501.91 


44,135.93 


15,486.48 


138,962.50 


Percentage of net debt to total assets 


60.1 


36.7 


19.2 


59.0 


15.7 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



299 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



Comber 
P.V. 


Cottam 
P.V. 


Courtright 
348 


Dashwood 
P.V. 


Delaware 
P.V. 


Dorchester 
P.V. 


Drayton 
559 


Dresden 
1,488 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 
















523.00 


7,231.00 


9,112.46 


6,515.06 


3,402.64 


3,764.27 


8,048.67 


9,333.37 


18,494.68 


3,422.04 

2.459.87 

384.93 


1,538.31 

1,778.79 

359.43 


1,225.40 
880.37 
425.08 


1,600.44 

1,378.45 

353.42 


914.44 
962.46 
148.08 


3,286.91 

2,411.76 

496 . 74 


3,328.48 

3,254.24 

673.50 


7,524.07 
5,912.96 
1,127.48 


977.24 


220.64 


558.67 


291.87 


203.81 


328.41 


401.02 


553.99 
















4,815.01 


































14,475.08 
3,261.56 


13,009.63 
3,366.01 


9,604.58 
686.28 


7,026.82 

1,351.20 

1,500.00 

6.70 


5,993.06 

1,026.21 

2,500.00 

309.09 


14,572.49 

2,101.25 

2,000.00 

67.93 


16,990.61 

484.02 

5,000.00 

109.57 


38,951.19 

1,024.08 
2,000.00 


291.61 


226.38 


25.43 


1,610.34 
565.40 


















11,265.98 


1,912.56 


3,068.73 


4,929.81 


1,607.07 


3,991.12 


6,777.75 


17,862.77 
120.00 


















29,294 ?3 


18,514.58 


13,385.02 


14,814.53 


11,435.43 


22,732.79 


29,361.95 


62,133.78 


















29.294.23 


18,514.58 


13,385.02 


14,814.53 


11,435.43 


22,732.79 


29,361.95 


62,133.78 


1,633 6? 


6,866.34 


3,508.45 
251.67 


2,131.19 
89.19 


2,161.11 

35.44 


2,479.56 
234.40 


6,415.08 
1,051.56 


726.04 
1,083.75 








19.85 


80.00 








15.00 




120.00 














1.653.47 


6,946.34 


3,760.12 


2,220.38 


2,196.55 


2,728.96 


7,466.64 


1,929.79 


11.26S 98 
4,535.27 


1,912.56 
2,422.63 


3,068.73 
1,103.15 


4,929.81 
1,917.52 


1,607.07 
869.58 


3,991.12 
1,585.97 


6,777.75 
5,133.06 


17,862.77 

4,918.02 

225.00 


















15,801 75 


4,335.19 


4,171.88 


6,847.33 


2,476.65 


5,577.09 


11,910.81 


23,005.79 


6,066.38 


2,133.88 


4,629.90 


1,268.81 


1,838.89 


1,820.44 


3,084.92 


15,512.21 


5,773.13 


5,099.17 


823.12 


4,478.01 


4,923.34 


12,606.30 


6,899.58 


21,685.99 


11,839.51 


7,233.05 


5,453.02 


5,746.82 


6,762.23 


14,426.74 


9,984.50 


37,198.20 


29.294.23 


18,514.58 


13,385.02 


14,814.53 


11,435.43 


22,732.79 


29,361.95 


62,133.78 


9.2 


41.8 


36.4 


22.4 


22.3 


14.5 


33.1 


4.1 



300 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Drumbo 
P.V. 


Dublin 
P.V. 


Dundas 

5,138 


Dunnville 
3,615 


Dutton 


Population 


761 






Assets 

Lands and buildings 


$ c. 


$ c. 


$ c. 
12,111.11 
13,396.22 
50,052.10 


$ c. 

3,356 09 

27,302.17 

36,699.01 


$ c. 


Substation equipment . . 








Distribution system — overhead . . . 
Distribution system — underground 
Line transformers. . 


4,552.59 


5,787.61 


9,086.84 


1,537.50 

1,863.92 

262.27 


897.65 
874.11 
544.86 


19,610.94 

19,427.63 

10,834.15 

1,154.52 

8,158.01 


18,110.09 

15,836.44 

8,012.37 


3,425.25 


Meters 


3,297.10 


Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


626.14 


257.95 


787.06 


5,788.34 


338.12 


Old plant 






1,867.38 


10,717.62 




Other plants not distributed 




















Total plant 


8,474.23 
2,878.65 


8,891.29 
269.38 


136,612.06 

11,192.92 

1,500.00 

4,375.02 

439.24 


125,822.13 

35.00 

10,000.00 

7,493.12 

886.01 


16,773.45 






Securities and investments 


6,000.00 


Accounts receivable 

Inventories 


294.88 
54.53 


229.23 


430.27 
22.82 


Sinking fund on local debentures 






Equity in H-E.P.C. systems 

Other assets 


3,658.36 


3,357.12 


81,992.63 
2,084.98 


32,056.77 


11,117.92 
120.17 












Total assets 


15,360.65 


12,747.02 
671.75 


238,196.85 


176,293.03 


34,464.63 


Deficit 














Total 


15,360.65 


13,418.77 


238,196.85 


176,293.03 


34,464.63 






Liabilities 

Debenture balance 


2,431.53 
61.91 


1,345.99 
858.79 


25,859.07 
1,743.12 


49,929.04 

8,571.83 
2,394.44 
1,225.35 


4,758.84 


Accounts payable 




Bank overdraft .... 


87.61 


Other liabilities. . 






3,086.83 


47.36 










Total liabilities 


2,493.44 


2,204.78 


30,689.02 


62,120.66 


4,893.81 






Reserves 

For equity in H-E.P.C. systems . . . 
For depreciation 


3,658.36 
2,933.41 


3,357.12 
3,002.86 


81,992.63 

41,922.00 

350.52 


32,056.77 
24,741.85 


11,117.92 
5,650.56 


Other reserves 














Total reserves 


6,591.77 


6,359.98 


124,265.15 


56,798.62 


16,768.48 






Surplus 

Debentures paid 


2,068.47 


4,854.01 


27,140.93 


25,570.96 


3,648.65 






Operating surplus 


4,206.97 




56,101.75 


31,802.79 


9,153.69 








Total surplus 


6,275.44 


4,854.01 


83,242.68 


57,373.75 


12,802.34 






Total liabilities, reserves and surplus 


15,360.65 


13,418.77 


238,196.85 


176,293.03 


34,464.63 


Percentage of net debt to total assets 


21.3 


23.4 


18.9 


43.0 


20 9 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



301 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



East 

Windsor 

14,333 


East York 
Twp. 


Elmira 
2,642 


Elora 
1,144 


Embro 

455 


Erieau 
264 


Erie 

Beach 

23 


Essex 

1,888 


$ c. 


$ c 

16,946.49 

8,514.27 

281,256.98 


$ c. 
7,119.73 


$ c 
1,524.54 


$ c. 


$ c. 


$ c. 


$ c. 












174,118.92 


34,855.36 


17.136.3C 


9,588.07 


9,286.94 


1,889.54 


35,810.48 

442 55 


74,978.65 
60,661.87 


75,986.83 

140,084.77 

20,605.46 


15,509.18 

12,767.67 

1,380.05 


7,301.95 
5,803.86 
1,235.43 


3,039.64 

2,072.23 

535 . 73 


1,600.23 

2,300.97 

246.10 


613.17 

732.78 


15,011.34 

10,630.12 

1 548 10 


89,295.42 






3,439.78 


15,185.88 


3,817.89 


1,339.05 


69.45 


379.90 


375.03 


2,583.63 






2,168.08 


1,425.47 


429.25 


































402,494.64 
83,957.95 


558,580.68 

9,129.20 

2,812.91 

23,978.79 

6,841.18 


77,617.96 

402.84 


35,766.60 

56.17 

7,000.00 

574 16 

619.32 


15,734.37 

1,117.19 

1,000.00 

468.29 


13,814.14 


3,610.52 

377.32 


66,026.22 
6,822 20 






5,000.00 
3,250.40 


13,939.00 


350.46 


413.81 


307.31 














125,360.56 


116,767.89 


46,936.38 


22,693.58 


6,527.33 


2,938.52 


747.87 


15,657.28 


















625,752.15 


718,110.65 


125,307.64 


66,709.83 


24,847.18 


17,166.47 


5,043.02 


96,756.10 


















625,752.15 


718,110.65 


125,307.64 


66,709.83 


24,847.18 


17,166.47 


5,043.02 


96,756.10 


98,715/1 
27,803.76 


260,603.69 

52,687.72 

138.46 

14,270 65 


24,587.85 
3,021.39 


3,749.15 

518.81 

156.87 

35.00 


3,215.44 
135.95 


4,540.17 

1,124.94 

62.35 

15.00 


2,547.11 
18.33 


19,003.56 
1,186.17 


89,295.42 


678.65 






565 13 










215,814.89 


327,700.52 


28,287.89 


4,459.83 


3,351.39 


5,742.46 


2,565.44 


20,754.86 


125,360.56 

46,069.95 

430 . 24 


116,767.89 

54,274.59 

1,672.50 


46,936.38 
15,623.42 


22,693.58 
11,246.10 


6,527.33 
4,660.64 


2,938.52 
1,806.50 


747.87 
368.36 


15,657.28 

11,061.83 

950 00 
















171,860.75 






33,939.68 




4,745.02 




27,669.11 


50,284.29 


96,464.09 


12,580.65 


9,250.85 


4,284.56 


2,342.96 


752.89 


3,496.44 


187,792.22 


121,231.06 


21,879.30 


19,059.47 


6,023.26 


4,336.03 


608.46 


44,835.69 


238,076.51 


217,695.15 


34,459.95 


28,310.32 


10,307.82 


6,678.99 


1,361.35 


48,332.13 


625,752.15 


718,110.65 


125,307.64 


66,709.83 


24,847.18 


17,166.47 


5,043.02 


96,756.10 


30.7 


54.5 


36.0 


10.1 


18.3 


40.3 


59.7 


25.5 



302 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Etobicoke 
Twp. 


Exeter 
1,622 


Fergus 
2,559 


Fonthill 
862 






1,465 




Assets 

Lands and buildings 


$ c. 
26,109.75 


$ c. 
3,281.59 


$ c. 


$ c. 


$ c. 
6,447.40 


Substation equipment 






Distribution system — overhead . . . 
Distribution system — underground 


264,591.04 


26,558.89 


33,257.25 


11,172.41 


19,850.09 


Line transformers 


65,033.98 

51,454.97 

11,937.62 

2,689.44 

5,055.18 


10,205.65 

8,081.77 

953.11 


15,885.95 

11,763.08 

2,163.24 


4,877.07 
4,331.41 
1,031.00 


9,608.76 
9,289 58 


Meters 


Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


2,369.94 


2,219.08 


1,145.49 


3,872.65 


868.54 


Old plant 






2,546.59 




11,042 87 


Other plants not distributed 






















Total plant 


426,871.98 


51,300.09 

6,274.48 
3,000.00 
2,525.10 
2,034.19 


66,761.60 
1,032.62 


25,284.54 


59,477.18 
4,166 54 


Bank and cash balance 


Securities and investments 






7,500.00 




21,905.49 
5,431.65 


1,149.81 
108.80 


605.01 


3,161.98 
1,714.49 




Sinking fund on local debentures. . 






Equity in H-E.P.C. systems 

Other assets 


92,232.23 
4,782.46 


23,307.91 


28,771.67 


2,800.14 
219.24 


16,729.43 










Total assets 


551,223.81 


88,441.77 


97,824.50 


28,908.93 


92,749.62 


Deficit 














Total 


551,223.81 


88,441.77 


97,824.50 


28,908.93 


92,749.62 






Liabilities 

Debenture balance 


185,435.62 

28,000.00 

9,674.35 

7,471.90 


8,211.16 
191.98 


18,458.35 
1,893.70 


16,901.54 


10,654.92 


Accounts payable 




Bank overdraft 


1,049.04 
210.62 




Other liabilities 


104.25 


10.00 


26.06 






Total liabilities 


230,581.87 


8,507.39 


20,362.05 


18,161.20 


10,680.98 






Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


92,232.23 

61,087.59 

760.79 


23,307.91 

9,738.21 

85.90 


28,771.67 
7,874.37 


2,800.14 
1,677.44 


16,729.43 
11,921.44 


Other reserves 


50.00 










Total reserves 


154,080.61 


33,132.02 


36,646.04 


4,477.58 


28,700.87 






Surplus 

Debentures paid 


80,259.78 


11,788.89 


23,541.65 


5,598.46 


23,745.08 


Local sinking fund 




Operating surplus 


86,301.55 


35,013.47 


17,274.76 


671.69 


29,622.69 






Total surplus 


166,561.33 


46,802.36 


40,816.41 


6,270.15 


53,367.77 






Total liabilities, reserves and surplus 


551,223.81 


88,441.77 


97,824.50 


28,908.93 


92,749.62 


Percentage of net debt to total assets 


48.9 


13.1 


29.5 


69.5 


14.1 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



303 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



Gait 
14,036 


George- 
town 

2,187 


Glencoe 
800 


Goderich 
4,366 


Granton 
P.V. 


Guelph 
20,754 


Hagers- 
ville 
1,370 


Hamilton 
154,701 


$ c. 
200,400 85 


$ c. 


$ c. 


$ c. 
12,957.48 
34,402.48 
66,031.41 


$ c. 


$ c. 

13,380.18 

154,033.43 

173,856.72 


$ c. 
864.37 


$ c. 
929,378.58 


113,678.71 






4,320.71 


1,752,301.59 


230,512.67 


31,167.43 


20,906.98 


20,216.91 


1,207,106 47 
854,684.64 


117,283.95 
70,247.62 
72,290.44 


18,111.46 

13,451.90 

1,364.67 


6,311.20 
4,202.13 
1,714.63 


20,309.85 

17,907.69 

4,825.17 


1,533.55 

1,486.86 

163.37 


85,064.07 
90,097.57 
42,207.45 


9,850.72 

8,533.70 
1,040.67 


902,219.08 
625,551.46 
277,329.74 


25,070.72 


2,411.30 


3,383.07 


5,883.56 


113.08 


14,210.70 


1,040.63 


201,750.22 




2,209.80 




14,622.15 








104,252.86 






























829,484.96 


68,716.56 

1,183.55 

7,986.67 

1,691.33 

127.49 


36,518.01 
2,550.56 


176,939.79 
2,922.44 


7,617.57 

2,260.04 

2,000.00 

352.86 


572,850.12 
7,771.94 


41,547.00 

9,321.97 

12,000.00 

128.48 

33.00 


6,854,574.64 
118,868.31 






54,185.97 

12,370.61 

109 461 97 


1,351.21 


4,021.17 
1,196.78 


15,979.43 

23,315.15 

44,819.73 

368,952.35 


421,735.60 
158,083.35 






648,954.49 


313,276.52 
1,995.45 


55,732.50 
1,500.18 


10,750.22 


70,410.65 
1,802.96 


4,760.53 


47,251.46 


2,173,195.35 
341.92 














1,320,775.48 


136,938.28 


51,170.00 


257,293.79 


16,991.00 


1,033,688.72 


110,281.91 


10,375,753.66 


















1,320,775.48 


136,938.28 


51,170.00 


257,293.79 


16,991.00 


1,033,688.72 


110,281.91 


10,375,753.66 


308,324.47 
13,256.91 


10,694.02 
811.96 


8,559.83 


50,093.14 
1,434.08 


2,131.93 
238.11 


52,500.00 
22,450.71 


3,166.70 
1,960.06 


3,271,123.10 
296,978.57 


2 031 73 






5,473.56 


498.48 


20.00 


1,735.79 




2,374.39 




1,874,770.30 










329.086.67 


12,004.46 


8,579.83 


53,263.01 


2,370.04 


77,325.10 


5,126.76 


5,442,871.97 


313,276.52 

231,619.45 

34,953.02 


55,732.50 
19,269.84 


10,750.22 
6,727.56 


70,410.65 

57,114.55 

1,055.77 


4,760.53 
2,101.61 


368,952.35 

36,874.74 

837.88 


47,251.46 
7,639.27 


2,173,195.35 
883,459.87 
171,744.85 














579,848.99 


75,002.34 


17,477.78 


128,580.97 


6,862.14 


406,664.97 


54,890.73 


3,228,400.07 


209,677.48 
109,461 97 


9,305.98 


11,553.05 


45,994.91 


1,368.07 


92,499.99 

44,819.73 

412,378.93 


4,833.30 


947,902.02 
648,954.49 


92,700.37 


40,625.50 


13,559.34 


29,454.90 


6,390.75 


45,431.12 


107,625.11 


411,839.82 


49,931.48 


25,112.39 


75,449.81 


7,758.82 


549,698.65 


50,264.42 


1,704,481.66 


1,320.775.48 


136,938.28 


51,170.00 


257,293.79 


16,991.00 


1,033,688.72 


110,281.91 


10,375,753.66 


24.5 


14.8 


21.2 


28.5 


19.4 


11.6 


8.1 


66.3 



304 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 

Population 


Harriston 
1,293 


Harrow 
926 


Hensall 
719 


Hespeler 
2,784 


Highgate 
338 






Assets 

Lands and buildings 


$ c. 


$ c. 


$ c. 


$ c. 

4,474.73 

29,732.13 

30,580.07 


$ c. 


Substation equipment 

Distribution system — overhead . . . 
Distribution system — underground 

Line transformers 

Meters 

Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hvdraulic plant 


600.00 
21,945.86 








16.655.54 


12,370.10 


6,383.76 


7,416.42 
7,087.97 
1,192.80 


9.910.52 

5,831.12 

741.63 


4,428.42 

3,427.82 

612.83 


20,634.74 

12,264.99 

7,147.63 


2,109.25 

1,697.12 

453.91 


892.07 


303.39 


549.80 


603.89 


513.64 


Old plant 


1,001.43 




400.00 






Other plants not distributed 




















Total plant 


40,136.55 
431.61 


33,442.20 
6,274.16 


21,788.97 

3,475.78 

4,000.00 

47.20 


105,438.18 

2,570.18 

"4,734.05 
435.36 


11,157.68 


Bank and cash balance 


2,263.07 


Securities and investments 


2,305.54 


Accounts receivable 

Inventories 


338.14 
58.48 


297.16 


238.14 


Sinking fund on local debentures. . 








Equity in H-E.P.C. systems 

Other assets 


19,021.07 


11,158.25 


8,596.60 


56,882.64 


5,893.16 














Total assets 

Deficit 


59,985.85 


51,171.77 


37,908.55 


170,060.41 


21,857.59 














Total 


59,985.85 


51,171.77 


37,908.55 


170,060.41 


21,857.59 


Liabilities 

Debenture balance 

Accounts payable 

Bank overdraft 


10,235.76 
3,471.46 


8.251.50 
2,816.72 


7,130.11 
849 . 78 


34,897.47 
184.74 


3,050.55 


Other liabilities 




406 . 24 


55.50 


5.00 










Total liabilities 


13,707.22 


11,474.46 


8,035.39 


35,087.21 


3,050.55 






Reserves 

For equity in H-E.P.C. systems .- . . 
For depreciation 


19,021.07 
5,676.17 


11,158.25 
1,471.04 


8,596.60 
5,832.73 


56,882.64 

12,465.85 

500.00 


5,893.16 
3,333.64 












Total reserves 


24,697.24 


12,629.29 


14,429.33 


69,848.49 


9,226.80 






Surplus 

Debentures paid 


15,582.27 


3,748.50 


4,869 89 


42,673.04 


1,949.45 






Operating surplus 


5,999.12 


23,319.52 


10,573.94 


22,451.67 


7,630.79 






Total surplus 


21,581.39 


27,068.02 


15,443.83 


65,124.71 


9,580.24 






Total liabilities, reserves and surplus 


59,985.85 


51.171.77 


37,908.55 


170,060.41 


21,857.59 


Percentage of net debt to total assets 


33.5 


28.6 


27.4 


31.0 


19.1 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



305 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



H umber- 
stone 
2,265 


Ingersoll 
5,296 


Jarvis 
504 


Kingsville 
2,286 


Kitchener 
31,443 


Lambeth 
P.V. 


La Salle 
600 


Leaming- 
ton 

5,025 


$ c. 


$ c. 
15,064.45 
33,210.77 
55,296.05 


$ c. 


$ c. 
7,774.09 


$ c. 

179,685.67 

218,733.96 

313,555.64 

38,019.52 

172,698.35 

180,742.56 

64,926.44 

86,939.84 

20,676.96 


$ c. 


$ c. 


$ c. 
16,387 58 










7,085 62 


26,146.68 


9,408.06 


31,259.00 


6,931.29 


18,971 .34 


49,897.49 
11,971 67 


9,181.25 

7,621.55 

884.80 


27,142.19 

24,764.88 

3,980.93 

4,597.59 

11,236.70 


3,080.21 

2,358.05 

846.99 


13,218.19 

13,260.75 

1,439.82 

19,200.00 

52.50 


1,883.12 

2,184.61 

269.16 


6,716.60 

4,174.22 

946.49 


22,592.47 

22,504.36 

1,380.13 

15,178 49 


3,167.04 


707.52 


300.71 


1,660.69 


1,838.17 




19,098.54 






52,363.91 




































47,001.32 
3,986 70 


194,392.10 


16,400.83 
3,951.34 


86,204.35 

8,568.14 

8,000.00 

544.48 


1,328,342.85 


11,568.89 

1,530.06 

3,000.00 

231.98 


32,469.34 
7,165.32 
1,144.49 


148,835.98 
7,060 52 




11,716.57 

1,620.07 

1,474.48 

68,029.84 

105,017.04 

761.03 


15,000.00 
50,628.45 
10,763.23 


11,000.00 


452.04 


203.05 


785.96 














9,735.62 

1,138 44 


7,844.51 


21,171.01 


704,233.55 


5,287.52 


6,920.00 
1,361.14 


38,294.17 














62,314.12 


383,011.13 


28,399.73 


124,487.98 


2,108,968.08 


21,618.45 


49,060 . 29 


205,976.63 


















62,314.12 


383,011.13 


28,399.73 


124,487.98 


2,108,968.08 


21,618.45 


49,060.29 


205,976.63 


19,200.00 
169.07 


79,800.00 

10,172.70 

5,330.73 

5,358.62 


6,622.83 
1,510.97 


28,630.70 
3,155.02 


190,441.49 
48,568.96 
42,547.99 
88,094.26 


2,436 29 
648.04 


11,329.59 
14.00 


33,005.45 
331.10 


917.09 




20,882.22 


30.00 


381.03 


17,416.05 








20,286.16 


100,662.05 


8,133.80 


52,667.94 


369,652.70 


3,114.33 


11,724.62 


50,752.60 


9,735.62 
1,332.06 


105,017.04 

12,343.29 

857.40 


7,844.51 
2,211.32 


21,171.01 
14,531.37 


704,233.55 

247,520.58 

26,164.18 


5,287.52 
2,854.95 


6,920.00 

5,247.44 

980.11 


38,294.17 
19,175.90 












11,067.68 


118,217.73 


10,055.83 


35,702.38 


977,918.31 


8,142.47 


13,147.55 


57,470.07 


12,800.00 




3,877.17 


4,869.30 


321,708.51 


1,563.71 


4,170.41 


14,994 55 




68,029.84 
96,101.51 




18,160.28 


6,332.93 


31,248.36 


439,688.56 


8,797.94 


20,017 71 


82,759.41 


30,960.28 


164,131.35 


10,210.10 


36,117.66 


761,397.07 


10,361.65 


24,188.12 


97,753.96 


62,314.12 


383,011.13 


28,399.73 


124,487.98 


2,108,968.08 


21,618.45 


49,060.29 


205,976.63 


38.6 


13.0 


39.6 


39.7 


21.4 


19.0 


27.8 


23.3 



306 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Listowel 
2,665 


London 
73,173 


London 
Twp. 


Long 

Branch 

3,541 


Lucan 


Population 


590 






Assets 

Lands and buildings 


$ c. 
1,457.39 

"38,677.84 
2,897.25 
17,556.07 
15,946.16 
1,853.82 
1,348.66 
2,482.88 


$ c. 

446,297.17 

937,035.75 

775,097.74 

281,865.17 

288,604.36 

322,834.22 

66,972.71 

84,746.73 

87,103.97 


$ c. 


$ c. 


$ c. 


Substation equipment 








Distribution system — overhead . . . 
Distribution system — underground 


17,172.37 


51,871.03 


10,528.36 


Line transformers 


5,605.28 

3,782.72 

861.36 


11,667.28 

16,685.36 

4,212.21 


4,131 49 


Meters 


3,123 36 


Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


430.15 


518.96 


1,220.51 


455.52 


Old plant 


4,745.30 




1,733.80 




2,860 45 


Other plants not distributed 




















Total plant 


86,965.37 
13,684.45 


3,290,557.82 
82,325.47 


29,674.49 
5,179.48 


85,656.39 


21 529 33 


Bank and cash balance 


3,654.23 


Securities and investments 




5,000.00 


Accounts receivable 


398.63 


199,081.27 

81,210.59 

323,711.25 

1,276,199.72 

430.86 


1,606.66 


1,031.58 


5.30 


Inventories 




Sinking fund on local debentures. . 










Equity in H-E.P.C. systems 

Other assets 


40,935.07 


7,958.96 
112.32 


6,340.04 
2,362.03 


11,298.71 








Total assets 


141,983.52 


5,253,516.98 


44,531.91 


95,390.04 


41,487.57 


Deficit 
















Total 


141,983.52 


5,253,516.98 


44,531.91 


95,390.04 


41,487.57 






Liabilities 

Debenture balance 


7,689.73 
3,219.79 


917,970.20 
123,527.12 


11,006.23 
6.69 


25,368.14 
12,506.99 


4,324.21 


Accounts payable 


171.52 


Bank overdraft 




Other liabilities 


1,545.04 


85,177.59 


112.32 


2,362.03 


147.22 






Total liabilities 


12,454.56 


1,126,674.91 


11,125.24 


40,237.16 


4,642 "95 






Reserves 
For equity in H-E.P.C. systems . . . 
For depreciation 


40,935.07 
27,324.72 


1,276,199.72 

815,940.62 

79,389.72 


7,958.96 
4,290.81 


6,340.04 

13,202.97 

359.98 


11,298.71 
7,141.45 


Other reserves 












Total reserves 


68,259.79 


2,171,530.06 


12,249.77 


19,902.99 


18,440.16 






Surplus 

Debentures paid 


35,500.16 


663,929.80 
323,711.25 
967,670.96 


7,993.77 


14,936.46 


6,889.41 


Local sinking fund 




Operating surplus 


25,769.01 


13,163.13 


20,313.43 


11,515.05 






Total surplus 


61,269.17 


1,955,312.01 


21,156.90 


35,249.89 


18,404.46 






Total liabilities, reserves and surplus 


141,983.52 


5,253,516.98 


44,531.91 


95,390.04 


41,487.57 


Percentage of net debt to total assets 


11.1 


20.2 


30.2 


43.6 


15.4 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



307 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



Lynden 
P.V. 


Markham 
1,073 


Merlin 
P.V. 


Merritton 
2,544 


Milton 
1,828 


Milverton 
1,004 


Mimico 
6,454 


Mitchell 
1,571 


$ c. 
241 18 


$ c. 


% c. 


$ c. 

2,951.67 

32,689.04 

34,597.79 


$ c. 


$ c. 
237.20 


$ c. 
17,071.16 
38,461.02 
74,219 93 


$ c. 
19,388.71 








11,868.94 
20,602.04 


21,287.83 


4,774.11 


15,421.16 


8,042.18 


11,341.16 


28,998.95 


2,134.21 

1,595.60 

340.66 


7,872.35 

5,681.24 

750.76 


3,399.23 

2,057.70 

555.64 


7,320.28 
9,664.77 
4,676.11 


13,944.73 

13,091.00 

1,282.36 


7,565.80 

5,047.01 

737.16 


29,920.12 

28,091.34 

7,747.29 


8,807.77 

11,902.61 

3,698.59 


193.57 


1,560.51 


455.36 


3,210.44 


4,282.62 


773.05 


5,008.13 


931.79 






241.85 




3,092.54 






1,500 00 






























9,279.33 
866 . 20 


31,286.02 

1,963.31 

2,153.58 

696.00 


14,751.96 

3,007.41 

6,000.00 

712.68 


95,110.10 
6,854.90 


68,164.23 

5,363.01 

12,000.00 

5,708.73 

4,145.51 


25,701.38 

1,036.76 
2,000.00 
1,689.76 


200,518.99 
100.00 


96,516.25 

2,903.68 
1,000.00 


394 . 72 


3,538.18 


10,6i0.69 


5,769.11 
2,544.29 
















8,470.87 


9,223.04 


7,210.65 


51,801.81 


62,216.95 
139.85 


27,538.79 


74,423.84 
2,012.47 


25,154.35 














19,011.12 


45,321.95 


31,682.70 


157,304.99 


157,738.28 


57,966.69 


287,665.99 


133,887.68 


















19,011.12 


45,321.95 


31,682.70 


157,304.99 


157,738.28 


57,966.69 


287,665.99 


133,887.68 




30 


1,327.05 


728.19 


1,109.85 


2,675.00 


229.03 
1,010.65 
4,645.00 




280.76 


368.49 




65.00 






139.85 




106.00 












2,946.63 


1,307.00 


9,075.11 


20,792.13 


9,561.09 


4,141.31 


89,139.33 


474.49 


2.447.13 


5,420.72 


2,150.45 


5,720.91 


14,462.53 
1,492.45 


5,125.26 
675.00 


41,430.43 
2,749.18 


33,537.39 




























1,829.13 


10,131.93 


5,616.15 


12,122.27 


24,735.02 


8,033.69 


43,745.35 


22,295.22 


3,317. 3e 


19,239. U 


7,630.34 


66,867.87 


45,270.24 


12,452.64 


36,177.86 


52,426.23 


5,146.45 


29,371.15 


13,246.49 


78,990 . 14 


70,005.26 


20,486.33 


79,923.21 


74,721.45 


19,011.12 


45,321. 9< 


31.682.7C 


157,304.95 


157,738.28 


57,966.65 


287,665.99 


133,887.68 


27.9 


3.6 


37.0 


19.7 


9.8 


13.6 


41.8 


0.4 



308 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Moorefield 
P.V. 


Mount 

Brydges 

P.V. 


Newbury 
267 


New 

Hamburg 

1,426 


New 


Population 


Toronto 
7,280 






Assets 

Lands and buildings 


$ c. 


$ c. 


$ c. 


$ c. 

2,513.19 

1,167.55 

23,632.05 


$ c. 
43,745.98 


Substation equipment 










Distribution system — overhead . . . 
Distribution system — underground 
Line transformers 


2,980.96 


6,393.68 


6,422.17 


77,754.15 
8,605.69 


990 . 72 

1,202.26 

295.88 


1,709.69 

2,240.12 

689.49 


1,797.86 

1,187.32 

817.42 


6,512.94 
8,982.53 
2,065.70 


29,638.15 


Meters 


28,094.55 


Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


10,090.44 


348.35 


220.32 


486.13 


1,083.83 


7,428.83 


Old plant 






348.22 


5,242.56 




Other plants not distributed . 




















Total plant 


5,818.17 
2,099.55 


11,253.30 

2,774.13 

3,000.00 

719.98 


11,059.12 
773.06 


51,200.35 
25.00 


205,357.79 


Bank and cash balance 

Securities and investments 


50.00 


Accounts receivable 

Inventories 


8.64 


867.12 


1,045.55 
1,044.07 


22,695.89 


Sinking fund on local debentures 










Equity in H-E.P.C. systems 

Other assets 


3,564.98 


3,954.00 


2,459.74 


28,962.42 


233,643.69 
1,089.07 














Total assets 


11,491.34 


21,701.41 


15,159.04 


82,277.39 


462,836.44 


Deficit 
















Total 


11,491.34 


21,701.41 


15,159.04 


82,277 39 


462,836.44 






Liabilities 

Debenture balance 


1,339.73 
171.93 


2,349.77 
31.45 


4,400.00 


6,775.48 


4,018.49 


Accounts payable . . 


412.37 


Bank overdraft . . 




349.48 
119.50 


13,987.00 


Other liabilities 




70.00 


5.00 


5,089.07 








Total liabilities 


1,511.66 


2,451.22 


4,405.00 


7,244.46 


23,506.93 






Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


3,564.98 
2,044.16 


3,954.00 
2,115.30 


2,459.74 
2,343.93 


28,962.42 

10,464.13 

192.10 


233,643.69 
40,978.95 


Other reserves 


3,094.82 












Total reserves 


5,609.14 


6,069.30 


4,803.67 


39,618.65 


277,717.46 






Surplus 

Debentures paid 


3,160.27 


1,870.23 


5,354.39 


10,953.60 


3,981.51 


Local sinking fund 




Operating surplus 


1,210.27 


11,310.66 


595.98 


24,460.68 


157,630.54 






Total surplus 


4,370.54 


13,180.89 


5,950.37 


35,414.28 


161,612.05 


Total liabilities, reserves and surplus 


11,491.34 


21,701.41 


15,159.04 


82,277.39 


462,836.44 


Percentage of net debt to total assets 


19.1 


13.8 


34.7 


13.6 


10.2 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



309 



"A"— Continued 

Hydro Municipalities as at December 31 , 1933 



Niagara 
Falls 
18,507 


Niagara- 

on-the-Lake 

1,672 


North York 
Twp. 


Norwich 
1,126 


Oil Springs 
433 


Otterville 
P.V. 


Palmerston 
1,617 


Paris 
4,330 


$ c. 
132,198.34 


$ c. 

2,307.35 

16,048.36 

27,556.88 


$ c. 
28,248.83 


$ c. 
4,157.99 


$ c. 
1,296.76 


$ c. 


$ c. 


$ c. 
8,426.83 


229,660.23 




691.88 
26,298.27 


27,948.18 


190,325.96 


328,051.79 


11,050.93 


12,840.49 


7,068.45 


51,352.12 


157,091.98 
106,984.98 
117,345.32 


6,852.78 
7,707.66 
1,230.44 


79,115.36 
41,099.94 
156.00 
13,491.21 
20,507.44 


6,180.85 
6,818.57 
4,685.64 


5,670.91 

3,321.76 

308.24 


3,587.82 
2,227.30 
1,408.96 


9,844.50 
7,414.82 
2,179.10 


19,712.59 
19,291.30 
13,986.43 


14,475.01 


1,716.72 


1,585.11 


2,568.33 


142.00 


781.39 


731.08 


21,604.27 






3,509.82 






4,018.71 
































969,686.09 

27,754.32 


63,420.19 

744.73 


510,670 57 


37,988.91 

2,185.73 
3,000.00 
1,846.81 
1,285.36 


26,006.49 

3,055.32 

2,483.98 

753.59 

74.77 


14,434.53 
3,548.17 


51,228.67 
315.28 


141,448.53 
5,489.68 




4,304.59 
. 6,321.28 

82.97 


18,500.00 


21,267.90 
16,116.47 


2,412.18 
1,448.52 


884.28 


341.95 
121.30 


838.78 








322,289.01 
25,951.10 


16,284.04 
52.05 


49,580.68 


21,467.24 


14,703.00 


4,586.52 


24,034.50 


65,116.46 
















1,383,064.89 


84,361.71 


570,960.09 


67,774.05 


47,077.15 


23,453.50 


76,041.70 


231,393.45 


















1,383,064.89 


84,361.71 


570,960.09 


67,774.05 


47,077.15 


23,453.50 


76,041.70 


231,393.45 


351,446.59 
50,114.43 


21,359.37 
565.87 


371,831.09 
223.18 


6,024.98 
223.63 


4,945.29 
1,507.58 


719.34 
256.93 


4,157.76 
724.44 


9,461.15 
548.79 


14,997.41 


50.00 


18,633.22 


107.50 




10.00 


237.50 




416,558.43 


21,975.24 


390,687.49 


6,356.11 


6,452.87 


986.27 


5,119.70 


10,009.94 


322,289 01 

135,074.09 

11,097.41 


16,284.04 

8,728.32 


49,580.68 
56,045.34 


21,467.24 
4,828.54 
1,000.00 


14,703.00 
6,123.17 


4,586.52 
3,953.07 


24,034.50 

6,287.98 

491.67 


65,116.46 

58,963.83 

175.00 














468,460 51 


25,012.36 


105,626.02 


27,295.78 


20,826.17 


8,539.59 


30,814.15 


124,255.29 


338,796.41 


15,142.05 


71,190.78 


7,731.02 


11,776.02 


3,780.66 


22,842.24 


82,538.85 


159,249.54 


22,232.06 


3,455.80 


26,391.14 


8,022.09 


10,146.98 


17,265.61 


14,589.37 


498,045.95 


37,374.11 


74,646.58 


34,122.16 


19,798.11 


13,927.64 


40,107.85 


97,128.22 


1,383,064.89 


84.361.71 


570,960.09 


67,774.05 


47,077.15 


23,453.50 


76,041.70 


231,393.45 


39.2 


32.3 


73.0 


13.7 


19.9 


5.2 


9.8 


6.0 



310 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality. . 


Parkhill 
998 


Petrolia 
2,569 


Plattsville 
P.V. 


Point 

Edward 

1,211 


Port 


Population 


Colborne 
6,006 






Assets 

Lands and buildings 


$ c. 


$ c. 

900.00 

2,403.55 

43,154.86 


$ c. 


$ c. 


$ c. 
22,561.01 


Substation equipment 








Distribution system — overhead . . . 
Distribution system — underground 
Line transformers 


15,970.73 


4,116.10 


21,201.15 


88,265.47 


4,239.63 

4,284.93 

898 . 23 


26,133.29 

14,951.86 

4,849.35 


1,890.66 

1,921.31 

147.15 


6,752.07 
4,938.70 
3,060.75 


24,486.11 


Meters 


21,939.13 


Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


4,544.86 
16,611.59 


1,364.13 


5,567.23 


535.92 


503.14 


7,355.75 


Old plant 




3,389.94 






9,929.60 


Other plants not distributed 






















Total plant 


26,757.65 
1,324.87 


101,350.08 

5,040.77 
8,400.00 
4,845.31 
1,113.27 


8,611.14 

598.90 

" ' 290 ' 63 


36,455.81 

339.69 

13,000.00 

3,731.10 


195.693.52 




2,030.85 




1,500.00 


Accounts receivable 


211.30 


10,700.96 




3,562.98 


Sinking fund on local debentures. . 










Equity in H-E.P.C. systems 


10,093.35 


58,101.13 
607.00 


5,100.27 


25,866.17 


49,150.47 












Total assets 


38,387.17 


179,457.56 


14,600.94 


79,392.77 


262,638.78 


Deficit 
















Total 


38,387.17 


179,457.56 


14,600.94 


79,392.77 


262,638.78 






Liabilities 

Debenture balance 


6,053.94 


24,250.57 
2,655.90 


2,829.93 


7,995.2? 
1,973.33 


93,441.20 




7,259.53 










75.00 


607.00 






20,244.27 












6,128.94 


27,513.47 


2,829.93 


9,968.55 


120,945.00 






Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


10,093.35 
5,061.97 


58,101.13 

26,730.46 

462.12 


5,100.27 
2,805.33 


25,866.17 

8,646.12 

300.00 


49,150.47 
30,837.14 




1,424.82 










Total reserves 


15,155.32 


85,293.71 


7,905.60 


34,812.29 


81,412.43 






Debentures paid 


8,576.08 


25,749.43 


2,407.07 


9,004.78 


52,558.80 






Operating surplus 


8,526.83 


40,900.95 


1,458.34 


25,607.15 


7,722.55 






Total surplus 


17,102.91 


66,650.38 


3,865.41 


34,611.93 


60,281.35 






Total liabilities, reserves and surplus. 


38,387.17 


179,457.56 


14,600.94 


79,392.77 


262,638.78 


Percentage of net debt to total assets 


21.7 


22.3 


29.8 


18.6 


52.9 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



31 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



Port 
Credit 
1,650 


Port 

Dalhousie 

1,331 


Port 
Dover 
1,680 


Port 

Rowan 

674 


Port 

Stanley 

723 


Preston 
6,138 


Princeton 
P.V. 


Queenston 
P.V. 


$ c. 
675.00 


$ c. 


$ c. 
248.75 


$ c. 


$ c. 
1,570.80 


$ c. 


$ c. 


$ c. 








50,602.15 
90,548.28 






24,693.75 


18,560.05 


29,878.70 


9,650.37 


20,483.81 


4,228.15 


7,594.07 


9,881.98 
9,266.13 
4,922.71 


9,272.89 
9,380.26 
1,041.19 


10,285.81 
6,959.06 
2,621.53 


1,676.62 

1,815.68 

888.04 


11,456.32 
9,348.18 
1,619.18 


47,835.53 

38,805.22 

5,418.03 


2,473.48 

1,223.65 

185.35 


1,911.85 

1,536.99 

422.43 


880.99 


2,304.88 


2,418.27 


701.53 


5,795.39 


6,948.89 


64.35 


2,081.11 




6,018.38 






577.51 


32,126.75 
































50,320.56 
3,030.30 


46,577.65 

1,564.01 
3,000.00 
2,472.02 


52,412.12 
4,526.71 


14,732.24 
86.36 


50,851.19 

3,532.64 
3,000.00 
1,359.00 


272,284.85 

16,822.25 

6,000.00 

15,974.69 

225.63 


8,174.98 
2,211.42 


13,546.45 
132.20 


1,806.68 


3,167.51 


256.29 


1,030.52 


269.27 




2,763.77 
16,815.86 












19,681.98 
402.42 


12,733.61 


3,408.20 


22,072.23 


155,142.27 


4,534.68 


3,708.42 


















75,241.94 


73,193.31 


72,839.95 


18,483.09 
6,119.26 


80,815.06 


466,449.69 


15,951.60 


17,656.34 
















75,241.94 


73,193.31 


72,839.95 


24,602.35 


80,815.06 


466,449.69 


15,951.60 


17,656.34 


8,150 07 
2,886.10 


9,830.08 
187.03 


10,502.73 
3,517.26 


8,914.18 
8,410.10 


7,406.13 
655.00 


51,651.54 
6,720.30 


1,918.27 
110.75 


5,635.49 
38.97 


370.00 




642.50 




30.01 


1,317.94 
















11,406.17 


10,017.11 


14,662.49 


17,324.28 


. 8,091.14 


59,689.78 


2,029.02 


5,674.46 


19,681.98 

13,033.01 

198.71 


16,815.86 

4,352.20 
800.00 


12,733.61 
7,809.93 


3,408.20 
1,784.05 


22,072.23 
9,232.04 


155,142.27 

93,620.87 

103.59 


4,534.68 
2,287.98 


3,708.42 
2,540.45 














32,913.70 


21,968.06 


20,543.54 


5,192.25 


31,304.27 


248,866.73 


6,822.66 


6,248.87 


6,349.93 


12,669.92 

2,763.77 
25,774.45 


18,497.27 


2,085.82 


11,543.87 


101,148.46 


1,631.73 


3,864.51 


24,572.14 


19,136.65 




29,875.78 


56,744.72 


5,468.19 


1,868.50 








30,922.07 


41,208.14 


37,633.92 


2,085.82 


41,419.65 


157,893.18 


7,099.92 


5,733.01 


75.241.94 


73,193.31 


72,839.95 


24,602.35 


80,815.06 


466,449.69 


15,951.60 


17,656.34 


20.5 


13.5 


24.4 


114.9 


13.8 


19.2' 


17.8 


40.7 



312 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 

Population 


Richmond 
Hil 
1,270 


Ridgetown 
1,942 


Riverside 
5,125 


Rockwood 
P.V. 


Rodney 

757 


Assets 

Lands and buildings 


$ c. 


$ c. 


$ c. 
2,379.31 


$ c. 
79.00 


$ c. 


Substation equipment 

Distribution system — overhead . . . 
Distribution system — underground 

Line transformers 

Meters 

Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


600.00 
10,471.67 


1,024.24 

21,427.18 




90,947.15 


7,565.39 


11,203.12 


7,803.75 
4,754.84 
1,334.77 

" 35 '. 23 


9,768.42 
9,403.96 
3,533.41 
1,431.73 
2,379.28 


31,354.96 
22,650.71 


2,481.27 

2,802.39 

561.22 


2,971.48 

3,527.15 

622.69 


17,030.71 
4,571.45 




455.65 


771.10 


Old plant 




5,088.46 






700.00 


Other plants not distributed 






















Total plant 


25,000.26 
4,388.52 


54,056.68 

50.00 

13,000.00 

574.08 

870.21 


168,934.29 


13,944.92 


19,795.54 


Bank and cash balance 


1,774.92 


Securities and investments 






3,000.00 


Accounts receivable 

Inventories 


2,574.51 
149.92 


9,101.58 


140.79 
114.98 


421.61 


Sinking fund on local debentures. . 




Equity in H-E.P.C. systems 

Other assets 


8,304.53 


23,153.15 


43,095.44 


6,373.61 
43.15 


6,962.59 












Total assets 


40,417.74 


91,704.12 


221,131.31 


20,617.45 


31,954.66 


Deficit 
















Total 


40,417.74 


91,704.12 


221,131.31 


20,617.45 


31,954.66 


Liabilities 

Debenture balance 

Accounts payable 

Bank overdraft 


4,153.98 
234.61 


6,395.74 

1,491.11 

2,378.61 

335.00 


53,888.22 
3,945.89 
1,550.98 

17,030.71 


2,345.00 


5,332.25 
394.84 


17.62 
41.00 




Other liabilities 


127.22 


140.00 






Total liabilities 


4,515.81 


10,600.46 


76,415.80 


2,403.62 


5,867.09 


Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


8,304.53 
1,319.76 


23,153.15 
10,897.16 


43,095.44 

25,990.34 

299.70 


6,373.61 
4,144.31 


6,962.59 
1,682.26 


Other reserves. . 














Total reserves 


9,624.29 


34,050.31 


69,385.48 


10,517.92 


8,644.85 


Surplus 

Debentures paid 


8,046.02 


13,060.25 


28,611.78 


2,155.00 


3,167.75 


Local sinking fund 




Operating surplus 


18,231.62 


33,993.10 


46,718.25 


5,540.91 


14,274.97 


Total surplus 


26,277.64 


47,053.35 


75,330.03 


7,695.91 


17,442.72 






Total liabilities, reserves and surplus 


40,417.74 


91,704.12 


221,131.31 


20,617.45 


31,954.66 


Percentage of net debt to total assets 


14.1 


13.6 


36.8 


16.9 


23.5 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



313 



4 'A"— Continued 

Hydro Municipalities as at December 31, 1933 



St. Catharines 
26,192 


St. Clair 
Beach 


St. George 
P.V. 


St. Jacobs 
P.V. 


St. Marys 
4,016 


St. Thomas 
16,275 


Sandwich 
11,017 


$ c. 
47,378.92 


$ c. 


$ c. 


$ c. 


$ c 

3,000.00 

26,975.49 

56,424.90 


$ c. 

73,253.59 

110,241.39 

111,816.38 

36,690.67 

53,685.43 

68,100.59 

21,259.32 

3,693.04 

9,527.13 


$ c. 
541.70 


115,063.83 








4,097.56 


207,545.05 


7,918.75 


5,935.34 


6,461.28 


107,887.10 


141,812.77 
88,567.66 
18,485.98 


2,726.36 
1,443.71 


2,729.42 

2,890.56 

286.41 


2,539.38 

2,662 28 

390.26 


18,843.29 

22,018.71 

5,074.74 


47,269.29 
50,421.88 
11,665.76 


29,486.71 




51,239.13 


38,196.14 


149.27 


374.18 


460.55 


3,790.51 


7,938.60 


7,792.05 








20,696.85 




4,148.96 




























694,329.11 
2,678.62 


12,238.09 


12,215.91 
73 . 10 


12,513.75 

21.37 

3,000.00 

59.96 


156,824.49 
25.00 


488,267.54 

18,521.87 

47,758.42 

16,627.27 

8,962.59 


285,209.98 
2,295.07 






21,659.37 


34,500.84 
474.38 


1,174.22 


289.61 

24.48 


. 3,103.68 

3,087.90 

1,375.88 

76,957.11 


18,487.21 
393 . 72 


68,010.06 








290,602.66 


3,600.11 


7,663.23 


7,966.38 


264,228.94 


125,752.20 
20,693.14 
















1,090,595.67 


17,012.42 


20,266.33 


23,561.46 


241,374.06 
215.82 


844,366.63 


474,490.69 














1,090,595.67 


17,012.42 


20,266.33 


23,561.46 


241,589.88 


844,366.63 


474,490.69 


209,961.24 
24,896.78 


3,663.73 
237.29 
345.67 


3,344.03 


1,759.45 
392.27 


40,839.90 

2,099.66 

1,689.09 

117.50 


27,957.27 
4.60 


97,856.41 


14,000.00 






29,792.71 


87.50 




12,188.74 


82,478.25 










278,650.73 


4,246.69 


3,431.53 


2,151.72 


44,746.15 


40,150.61 


180,334.66 


290,602.66 

133,334.99 

7,047.10 


3,600.11 

2,298.68 

12.67 


7,663.23 
1,874.75 


7,966.38 
2,758.05 


76,957.11 

44,444.57 

659.05 


264,228.94 

97,309.67 

487.21 


125,752.20 
37,335.30 










430,984. 75 


5,911.46 


9,537.98 


10,724.43 


122,060.73 


362,025.82 


163,087.50 


92,061.67 
68,010.06 


2,677.72 


2,655.97 


4,240.55 


73,407.12 
1,375.88 


110,986.80 


47,716.62 


220,888.46 


4,176.55 


4,640.85 


6,444.76 


331,203.40 


83,351.91 








380,960.19 


6,854.27 


7,296.82 


10,685.31 


74,783.00 


442,190.20 


131,068.53 


1,090,595.67 


17,012.42 


20,266.33 


23,561.46 


241,589.88 


844,366.63 


474,490 . 69 


32.3 


31.6 


27.2 


13.8 


26.6 


6.3 


43.4 



314 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Sarnia 
17,801 


Scarboro' 
Twp. 


Seaforth 
1,692 


Simcoe 
5,397 


Spring- 
field 
379 


Population 






Assets 

Lands and buildings 


$ c. 
111,796.86 
199,300.27 
214,746.25 


$ c. 

16,585.49 

301.95 

269,600.83 


$ c. 

1,290.34 

5,999.16 

28,114.36 


$ c. 

8,442.41 

22,906.67 

50,178.74 

1,417.87 

24,481.89 

24,074.70 

5,589.97 

3,500.00 

6,016.27 


$ c. 


Substation equipment 




Distribution system — overhead . . . 
Distribution system — underground 

Line transformers 

Meters 


7,872.62 


79,089.95 

71,879.72 

25,306.78 

7,482.11 

24,057.28 


59,762.65 
63,913.90 
19,810.03 


9,670.10 
8,749.87 
1,414.55 


2,374.19 
1,981.74 


Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


546.24 


12,685.69 


574.76 


691.36 


Old plant 


55,445.72 






927.92 




Other plants not distributed 




















Total plant 


789,104.94 
2,683.40 


442,660.54 
32,297.54 


55,813.14 

2,455.26 

100.00 

5,728.70 

2,362.54 


147,536.44 
8,571.22 


13,466.15 


Bank and cash balance 


62.84 


Securities and investments 


4,500.00 


Accounts receivable 


41,545.26 
19,011.08 


13,062.13 


2,564.49 
112.00 


851.04 


Inventories 




Sinking fund on local debentures 






Equity in H-E.P.C. systems 

Other assets 


328,029.30 
3,520.00 


84,438.89 


37,447.48 


49,310.53 


5,308.21 












Totals assets 


1,183,893.98 


572,459.10 


103,907.12 


208,094.68 


24,188.24 


Deficit .... 
















Total 


1,183,893.98 


572,459.10 


103,901.12 


208,094.68 


24,188.24 






Liabilities 

Debenture balance . 


129,466.79 
22,802.79 


219,448.13 
26,383.30 




54,937.81 
591.45 


3,610.93 


Accounts payable 

Bank overdraft 


316.44 


65.49 


Other liabilities 


13,391.67 


25,952.79 


35.00 


3,625.00 


52.00 


Total liabilities 


165,661.25 


271,784.22 


351.44 


59,154.26 


3,728.42 






Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


328,029.30 

116,801.40 

944.69 


84,438.89 

63,544.07 

4,202.94 


37,447.48 

18,367.28 

1,106.96 


49,310.53 
18,402.37 


5,308.21 
2,330.06 


Other reserves 










Total reserves 


445,775.39 


152,185.90 


56,921.72 


67,712.90 


7,638.27 






Surplus 

Debentures paid 


208,533.21 


71,120.15 


25,000.00 


20,497.09 


5,889.07 


Local sinking fund 




Operating surplus. . 


363,924.13 


77,368.83 


21,633.96 


60,730.43 


6,932.48 






Total surplus . 


572,457.34 


148,488.98 


46,633.96 


81,227.52 


12,821.55 






Total liabilities, reserves and surplus 


1,183,893.98 


572,459.10 


103,907.12 


208,094.68 


24,188.24 


Percentage of net debt to total assets 


18.0 


55.7 


0.5 


35.7 


19.7 



934 



HYDRO-ELECTRIC POWER COMMISSION 



315 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



Stamford 
Twp. 


Stouffville 
1,105 


Stratford 
18,869 


Strathroy 
2,879 


Sutton 
809 


Tavistock 
1,042 


Tecumseh 
2,546 


Thames- 
ford 
P.V. 


$ c. 
7.196.71 


$ c. 


$ c 
135,191.94 
136,903.19 
153,378.90 


$ c. 

8,741.01 

22,194.32 

48,919.46 


$ c. 


$ c. 
234.02 


$ c. 


$ c. 


37,384.60 










124,563.22 


12,608.07 


19,752.18 


13,273.34 


34,572.41 


7,691.45 


43,451.31 

30,693.29 

9,191.78 


3,903.57 
4,108.78 
1,445.52 


93,765.92 
85,894.94 
21,797.39 


19,238.16 
14,441.11 

5,814.75 


6,797.85 
5,633.71 
1,571.88 


6,251.28 

4,786.61 

931.82 


10,039.18 
10,501.08 


2,625.63 

2,549.77 

290.65 




4,760.95 
1,262.48 




10 : 164.65 


497.41 


17,534.24 


2,293.90 


1,593.88 


586.46 


343.89 


13,743.66 


3,866.37 


16,150.00 


12,343.15 


675.00 
































276,389.22 
4,654.19 


26,429.72 

4,165.17 

5,000.00 

439.03 

27.20 


660,616.52 

30,599.19 

21,900.00 

29,556.48 

9,679.56 

209,445.54 

341,228.19 

2,283.71 


133,985.86 
8,514.85 


36,024.50 
2,403.39 


26,063.53 

854.69 

3,596.30 

766.81 


61,136.10 


13,501.39 
626.47 






7,500.00 


14,089.24 


3,546.01 
2,536.70 


1,385.47 
21.00 


2,886.87 




7,185.81 












48,099.73 
5.170.62 


7,758.09 


47,541.31 
541.59 


7,140.47 


24,238.67 


13,344.22 


9,606.22 
34.00 














355,588.81 


43,819.21 


1,305,309.19 


196,666.32 


46,974.83 


55,520.00 


77,367.19 


31,268.08 


















355.588.81 


43,819.21 


1,305,309.19 


196,666.32 


46,974.83 


55,520.00 


77,367.19 


31,268.08 


171,033.8/ 
10,205.15 


6,628.45 


412,000.00 
54.64 


34,437.54 
192.76 


16,291.56 
2,266.91 


3,666.42 
105.83 


14,789.20 
3,250.03 
3,928.24 
4,760.95 


1,662.13 
76.48 








4,073.36 




2,283.71 


541.59 


47.30 




34.00 








185,312.38 


6,628.45 


414,338.35 


35,171.89 


18,605.77 


3,772.25 


26,728.42 


1,772.61 


48,099.73 

23,104.62 

2,375.00 


7,758.09 
2,075.19 


341,228.19 

208,434.19 

2,024.65 


47,541.31 
21,936.81 

522.15 


7,140.47 
4,860.12 


24,238.67 
7,536.71 


13,344.22 

10,279.95 

214.95 


9,606.22 

4,517.18 












73,579.35 


9,833.28 


551,687.03 


70,000.27 


12,000.59 


31,775.38 


23,839.12 


14,123.40 


69,244.30 


11,911.82 


43,800.00 

209,445.54 

86,038.27 


31.794.46 


9,708.44 


2,333.58 


11,210.80 


3,695.90 


27,452.78 


15,445.66 


59,699.70 


6,660.03 


17,638.79 


15,588.85 


11,676.17 


96,697.08 


27,357.48 


339,283.81 


91,494.16 


16,368.47 


19,972.37 


26,799.65 


15,372.07 


355.588.81 


43,819.21 


1,305,309.19 


196,666.32 


46,974.83 


55,520.00 


77,367.19 


31,268.08 


60.2 


18.4 


27.2 


23.3 


46.7 


12.1 


37.0 


8.0 



316 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Thames- 
ville 
754 


Thedford 

577 


Thorndale 
P.V. 


Thorold 
5,068 


Tilbury 
1,996 


Population 


Assets 

Lands and buildings 

Substation equipment 


$ c. 
681.69 


$ c. 


$ c. 


$ c. 
9,892.59 


$ c. 
969.46 








Distribution system — overhead . . . 
Distribution system — underground 

Line transformers 

Meters 


11,902.59 


9,228.39 


3,288.86 


31,057.12 


16,006.41 


5,160.49 
3,827.61 
1,379.42 


3,303.91 

2,206.01 

885.46 


1,559.98 

1,747.46 

181.19 


15,052.83 

20,502.73 

2,811.59 


12,699.77 
7,440.92 


Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


1,001.16 


895 . 68 


1,612.01 


310.45 


4,982.45 
13,244.74 


1,426.82 


Old plant 


4,445.68 


433.78 




3,049.47 


Other plants not distributed 




















Total plant 


28,293.16 

2,570.77 

6,000.00 

576.54 


17,669.56 

410.78 

1,000.00 

580.65 


7,087.94 
438.88 


97,544.05 
4,720.68 


42,594.01 


Bank and cash balance 


3,460.87 


Securities and investments 


10,000.00 


Accounts receivable 


605.86 


4,122.89 
152.13 


289.13 


Inventories 




Sinking fund on local debentures 










Equity in H-E.P.C. systems 

Other assets . 


9,545.28 


4,809.74 


5,154.87 


45,966.73 


24,728.27 
150.02 














Total assets 


46,985.75 


24,470.73 


13,287.55 


152,506.48 


81,222.30 


Deficit . 
















Total 


46,985.75 


24,470.73 


13,287.55 


152,506.48 


81,222.30 






Liabilities 

Debenture balance 


4,169.01 
11.97 


8,933.05 
61.82 


1,433.12 




6,661.95 


Accounts payable 


152.24 


325.40 


Bank overdraft 






Other liabilities 


178.00 


10.00 


17.50 


1,559.50 








Total liabilities 


4,358.98 


9,004.87 


1,450.62 


1,711.74 


6,987.35 






Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


9,545.28 
6,125.55 


4,809.74 
2,086.53 


5,154.87 

2,636.99 

100.00 


45,966.73 
23,997.30 


24,728.27 
10,340.80 


Other reserves 














Total reserves 


15,670.83 


6,896.27 


7,891.86 


69,964.03 


35,069.07 






Surplus 

Debentures paid 


7,018.79 


7,566.95 


1,653.36 


5,000.00 


7,338.05 


Local sinking fund 




Operating surplus 


19,937.15 


1,002.64 


2,291.71 


75,830.71 


31,827.83 






Total surplus 


26,955.94 


8,569.59 


3,945.07 


80,830.71 


39,165.88 






Total liabilities, reserves and surplus 


46,985 . 75 


24,470.73 


13,287.55 


152,506.48 


81,222.30 


Percentage of net debt to total assets 


11.6 


45.8 


17.8 


1.6 


12.4 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



317 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



Tillson- 
burg 
3,351 


Toronto 
626,674 


Toronto 
Twp. 


Trafalgar 

Twp. 
Area No. 1 


Trafalgar 

Twp. 
Area No. 2 


Walkerville 
10,681 


Wallaceburg 
4,343 


$ c. 
4,824 27 


$ c. 
5,400,813.30 
14,971,090.50 
6,227,078.98 
4,085,067.76 
3,561,045.50 
2,974,114.67 
480,484 . 65 


$ c. 
6,366.13 


$ c. 


$ c. 


$ c. 
147,518.53 
155,069.52 
153,627.02 


$ c. 
37,746.29 


13,937 52 






9,651.80 


41,024.22 


175,307.49 


20,294.72 


10,456.48 


55,679.80 


16,761.20 
15,824.40 
11,522 52 


49,332.62 

31,681.48 

3,717.44 


9,595.46 
4,741.17 


2,071.55 
1,309.65 


90,713.78 
69,783.88 


34,773.82 
19,637.22 
10,224.10 








187,172.22 
38,538.32 




4,570.72 


2,617,154.43 


3,139.02 


1,541.60 


314.16 


4,078.20 




3,585,379.99 


619.65 






18,335.05 


20,941.07 
























108,464.85 
540.39 


43,902,229.78 
387,096.74 


270,163.83 

6,335.94 

10,000.00 

8,641.64 


36,172.95 

1,299.64 

4,000.00 

572.86 


14,151.84 


860,758.32 

50.00 

31,119.99 

107,974.17 

25,442.15 


192,732.30 
8,947.86 


9,000 00 


2,000.00 
294 . 10 




2,375.17 
1,801 45 


1,614,289.78 

526,939.00 

6,121,128.19 

10,262,345.03 

75,259.49 


3,691.60 
5,636 29 












47,955.04 


48,982.20 
2,091.46 






356,447.26 
841.35 


102,741.31 


2,506.02 






1,750.57 










172,642.92 


62,889,288.01 


346,215.07 


42,045.45 


16,445.94 


1,382,633.24 


315,499.93 
















172,642.92 


62,889,288.01 


346,215.07 


42,045.45 


16,445.94 


1,382,633.24 


315,499.93 


10,138.34 
28 51 


26,457,233.36 
1,692,448.39 


60,920.24 


12,614.82 


9,461.15 


137,772.89 
22,305.24 
38,468.33 

205,072.72 


44,546.15 
701.54 








354.61 




2,506.02 




2,091.46 




1,750.57 












12,672.87 


28,149,681.75 


63,011.70 


12,614.82 


9,815.76 


403,619.18 


46,998.26 


47,955.04 


10,262,345.03 

7,214,466.03 

968,096.82 


48,982.20 

85,258.17 

862.42 






356,447.26 

125,031.63 

3,454.62 


102,741.31 


29,731.07 
500.00 


12,046.67 


1,193.00 


37,584.12 
287.99 










78,186.11 


18,444,907.88 


135,102.79 


12,046.67 


1,193.00 


484,933.51 


140,613.42 


25,861.66 


8,125,766.64 
6,121,128.19 
2,047,803.55 


43,079.76 


6,811.59 




161,486.11 


26,990.43 








55,922.28 


105,020.82 


10,572.37 


5,437.18 


332,594.44 


100,897.82 


81,783.94 


16,294,698 38 


148,100.58 


17,383.96 


5,437.18 


494,080.55 


127,888.25 


172,642.92 


62,889,288.01 


346,215.07 


42,045.45 


16,445.94 


1,382,633.24 


315,499.93 


10.2 


47.4 


20.6 


3.0 


59.7 


25.8 


21.4 



318 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



NIAGARA 

SYSTEM— Continued 



Municipality 


Wardsville 
214 


Water- 
down 
924 


Waterford 
1,168 


Waterloo 
8,563 


Watford 


Population 


956 


Assets 

Lands and buildings 


$ c. 


$ c. 
200.00 


$ c. 


$ c. 
14,454.37 
63,543.83 
90,368.32 


$ c. 


Substation equipment 








Distribution system — overhead . . . 
Distribution system — underground 
Line transformers 


5,003.72 


16,056.14 


15,772.78 


16,452.69 


1,665.49 

1,253.12 

519.36 


5,391.05 

5,594.64 

583.81 


7,201.37 
5,939.66 
3,231.62 


40,376.31 

34,817.28 

14,092.07 

3,106.80 

6,484.84 


5,411.56 


Meters 


5,200.57 


Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


807.31 


518.73 


411.29 


447.83 


2,022.23 


Old plant 


193.94 






24,160.67 


657.44 


Other plants not distributed .... 




















Total plant 


9,154.36 


28,236.93 
2,036.53 


32,593.26 

349.34 

5,300.00 

536.95 


291,404.49 
12,322.16 


30,551.80 


Bank and cash balance 


296.16 


Securities and investments 




5,500.00 


Accounts receivable 


974.40 


1,457.48 


2,170.24 

375.00 

11,255.78 

142,961.10 


1,097.07 


Inventories 


30.87 


Sinking fund on local debentures. . 










Equity in H-E.P.C. systems 

Other assets . 


1,876.72 


13,365.35 


17,475.90 


11,763.78 














Total assets 


12,005.48 


45,096.29 


56,255.45 


460,488.77 


49,239.68 


Deficit 
















Total 


12,005.48 


45,096.29 


56,255.45 


460,488.77 


49,239.68 






Liabilities 

Debenture balance 


3,893.41 

200.00 

95.95 






52,472.72 
14,654.51 


1,544.99 


Accounts payable 




400.59 




Bank overdraft 






Other liabilities 


70.00 




3,106.80 










Total liabilities 


4,189.36 


70.00 


400 . 59 


70,234.03 


1,544.99 






Reserves 

For equity in H-E.P.C. systems . . . 
For depreciation 


1,876.72 
1,912.84 


13,365.35 
6,758.54 


17,475.90 
8,962.52 


142,961.10 

93,685.60 

328.00 


11,763.78 
5,596.64 


Other reserves 


23.00 












Total reserves 


3,789.56 


20,123.89 


26,438.42 


236,974.70 


17,383.42 






Surplus 

Debentures paid 


3,668.99 


8,000.00 


7,745.53 


53,527.28 
11,255.78 
88,496.98 


8,168.22 


Local sinking fund 




Operating surplus 


357.57 


16,902.40 


21,670.91 


22,143.05 






Total surplus 


4,026.56 


24,902.40 


29,416.44 


153,280.04 


30,311.27 






Total liabilities, reserves and surplus 


12,005.48 


45,096.29 


56,255.45 


460,488.77 


49,239.68 


Percentage of net debt to total assets 


41.4 


0.2 


1.0 


22.1 


4.1 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



319 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



Welland 
10,668 


Wellesley 
P.V. 


West Lome 
814 


Weston 
4,736 


Wheatley 

724 


Windsor 
65,565 


Wood- 
bridge 

744 


Wood- 
stock 
10,956 


73,059.45 
56,576.25 






11,903.31 
32,737.85 
60,108.79 




312,236.33 
678,250.86 
754,463.75 
141,798.67 
343,932.20 
329,751.12 
37,377.41 
693,788.56 
125,740.85 




35,489.71 






' 14,843 '. 74 




93,838.15 


131,470.15 
7,470.91 


6,691.79 


11,321.69 


17,730.00 


101,168.78 


57,311.64 

56,249.15 

4,246.63 

36,513.75 


2,153.50 

2,464.94 

545.11 


4,274.36 

3,091.23 

643.57 


34,379 30 
22,587.91 
30,041.06 


4,443.64 
3,887.49 
1,659.26 


5,776.33 

4,273.32 

423.26 


55,243.46 
53,949.56 
15,068.12 


10,839.08 


127.38 


347.14 


6,313.68 


803.82 


817.20 


2,794.78 


50 069 48 




1,250.00 




2,569.50 


141,990.11 
































483,806.49 

4,340.71 
30,458.65 


11,982.72 
320.32 


20,927.99 

873,55 

3,000.00 

328.80 


198,071.90 
5,694.61 


28,207.45 

3,506.13 

1,500.00 

227.83 


3,559,329.86 

33,060.24 
112,463.80 
133,422.84 

84,923.23 

120,519.10 

1,056,217.61 


28,020.11 

357.47 

' 848.05 
18.36 


357,552.56 

26,166.79 
86,000.00 


20,702.86 
17,893.73 


51.17 


8,966.00 
165.00 


3,069.91 
374.63 


108,771.53 








50,999.37 


148,814.76 
5,169.65 


9,904.27 


16,699.36 


125,872.53 


6,384.47 


16,082.48 


210,352.26 
5,564.39 


















819,958.38 


22,258.48 


41,829.70 


338,770.04 


39,825.88 


5,099,936.68 


45,326.47 


740,079.91 


















819,958.38 


22,258.48 


41,829.70 


338,770.04 


39,825.88 


5,099,936.68 


45,326.47 


740,079.91 


257,249.38 
44,521.42 


1,747.84 
444.93 


5,145.27 
103.59 


38,410.61 


8,199.66 
353.07 


1,334,783.01 
65,350.00 


5,040.43 
3,052.14 


75,894.20 
4,589.08 








43,233.20 






2,155.46 


35.00 


750,036.31 


240.09 


5,564.39 










345,004.00 


2,192.77 


5,248.86 


40,566.07 


8,587.73 


2,150,169.32 


8,332.66 


86,047.67 


148,814.76 

112,923.96 

2,404.87 


9,904.27 
2,168.34 


16,699.36 
5,783.14 


125,872.53 
30,625.81 


6,384.47 
2,929.42 


1,056,217.61 
395,106.44 
138,012.99 


16,082.48 
6,628.66 


210,352.26 

125,853.55 

13,134.05 
















264,143.59 


12,072.61 


22,482.50 


156,498.34 


9,313.89 


1,589,337.04 


22,711.14 


349,339.86 


41,750.62 


5,752.16 


2,854.73 


31,621.83 


4,800.34 


655,217.02 
584,694.20 


3,459.54 


51,491.43 


60,288.64 


2,240.94 


11,243.61 


110,083.80 


17,123.92 


10,823.13 
14,282.67 


202,201.58 


210,810.79 


7,993.10 


14,098.34 


141,705.63 


21,924.26 


1,360,430.32 


304,692.38 


819,958.38 


22,258.48 


41,829.70 


338,770.04 


39,825.88 


5,099,936.68 


45,326.47 


740,079.91 


48.6 


17.7 


20.8 


19.0 


25.7 


43.4 


28.5 


6.2 



320 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



NIAGARA 
SYSTEM— Concluded 



Municipality 


Wyoming 
482 


York Twp. 


Zurich 
P.V. 


NIAGARA 


Population 


SYSTEM 
SUMMARY 






Assets 

Lands and buildings 


$ c. 


$ c. 


$ c. 


$ c. 

8,824,114.16 
20,837,708.34 
16,955,410.84 

5,556,486 79 


Substation equipment 








Distribution system — overhead. . . . 
Distribution system — underground 
Line transformers 


7,336.07 


772,073.02 


6,932.37 


. 1,257.61 

2,311.10 

289.62 




1,643.52 

2,270.21 

471.82 


8,154,866.70 
6,936,257.77 
1,744,843.70 
1,458,443.68 
3,663,846.72 
13,244 74 


Meters 




Street light equipment, regular .... 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


49,765.60 


805 . 20 


19,070.96 


240.77 


Old plant 






150.00 


4,403,238.16 
200,000.00 


Other plants not distributed 














Total plant 


11,999.60 

32.20 


840,909.58 
94,214.56 


11,708.69 

1,291.14 

2,000.00 

13.86 


78,748,461.60 

1,354,901.08 

735,567.45 

3,182,004.70 


Bank and cash balance 


Securities and investments 


Accounts receivable 


315.44 


13,089.47 


Inventories 


1,076,929.55 


Sinking fund on local debentures. . . 








8,016,069.90 


Equity in H-E.P.C. systems 

Other assets 


4,467.98 
45.00 




7,563.75 


23,196,330.36 


19,420.29 


249,586.23 








Total assets 


16,860.22 
2,112.46 


967,633.90 


22,577.44 


116,559,850.87 


Deficit 


14,494.35 










Total 


18,972.68 


967,633.90 


22,577.44 


116,574,345.22 






Liabilities 

Debenture balance 


1,639.52 
307.06 


409,365.43 
32,498.52 


3,742.80 
302.04 


38,275,850.97 


Accounts payable 


2,805,142.07 


Bank overdraft 


154,550.92 


Other liabilities 


45.00 




16.02 


3,724,456.24 








Total liabilities 


1,991.58 


441,863.95 


4,060.86 


44,960,000 . 20 






Reserves 

For equity in H-E.P.C. systems. . . . 
For depreciation 


4,467.98 
4,452.64 




7,563.75 
4,025.25 


23,196,330.36 


146,967.70 


13,330,347.14 


Other reserves 


1,589,857.32 












Total reserves 


8,920.62 


146,967.70 


11,589.00 


38,116,534.82 






Surplus 

Debentures paid 


8,060.48 


190,634.57 


1,848.81 


14,911,550.87 


Local sinking fund 


8,016,069.90 


Operating surplus 




188,167.68 


5,078.77 


10,570,189.43 








Total surplus 


8,060.48 


378,802.25 


6,927.58 


33,497,810.20 






Total liabilities, reserves and surplus 


18,972.68 


967,633.90 


22,577.44 


116,574,345.22 


Percentage of net debt to total assets 


32.8 


45.7 


27.0 


42.3 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



321 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



GEORGIAN BAY 
SYSTEM 



Alliston 
1,379 


Arthur 
1,037 


Barrie 

7,455 


Beaverton 
960 


Beeton 
584 


Bradford 
1,009 


Brechin 
P.V. 


Canning- 
ton 
851 


$ c. 


$ c. 


$ c. 
14,199.11 
15,279.30 
56,509.52 
66,437.67 
42,184.26 
40,238.97 
12,063.80 


$ c. 
299.50 


$ c. 


$ c 


$ c 


$ c. 


675 73 




428.50 
11,710.00 


388.50 
19,057.00 






26,609.18 


17,169.34 


20,956.37 


1,789.59 


10,008.17 


7,039.73 
7,110.66 
1,522.69 


3,961.15 

3,382.92 
767.21 


6,731.49 
5,618.48 
1,173.58 


2,188.63 
1,931.95 
1,169.54 


4,072.65 

3,898.73 

544.95 


1,126.71 
726.95 
212.44 


4,156.88 

4,214.51 

924.69 


2,565.49 


382.26 


7,612.84 


2,583.41 


1,433.38 


1,828.94 


546.92 


644.33 


7,846.49 


1,086.62 


42,634.32 


3,772.42 








3,609.37 




























53,369.97 
340.90 


26,749.50 

33.57 


297,159.79 
5,087.92 


41,135.25 

1,065.55 
9,000.00 
1,201.13 

17.85 


18,862.00 
493.59 


29,790.77 

1,945.87 

1,000.00 

2,950.55 

22.62 


4,402.61 

412.38 

1,077.07 


23,557.95 

10.00 
1,326.62 


2,475.70 


215.94 
10.20 


12,943.01 
. 94.77 


1,186.69 
11.22 


1,768.49 
175.92 






11,295.94 


10,746.86 


73,212.70 


12,230.73 


8,727.20 


9,628.32 


4,761.23 


9,119.57 


















67,482.51 


37,756.07 
11,514.07 


388,498.19 


64,650.51 


29,280.70 
1,590.95 


45,338.13 


10,653.29 


35,958.55 














67,482.51 


49,270.14 


388,498.19 


64,650.51 


30,871.65 


45,338.13 


10,653.29 


35,958.55 


25,981.75 
93.75 


17,642.69 
2,574.06 


26,798.16 
34,823.65 


6,623.12 
176.25 


10,128.17 

785.. 80 


18,182.07 
536.57 


2,153.26 
290.87 


7,967.85 

90.57 

437.82 






3.00 


378.47 




175.98 


21.85 












26,075.50 


20,216.75 


61,624.81 


7,177.84 


10,913.97 


18,894.62 


2,465.98 


8,496.24 


11,295.94 
13,193.34 


10,746.86 
10,949.22 


73,212.70 

59,932.40 

1,100.00 


12,230.73 
11,187.92 


8,727.20 
6,358.65 


9,628.32 
7,477.14 


4,761.23 
1,664.18 


9,119.57 
7,378.27 
















24,489.28 


21,696.08 


134,245.10 


23,418.65 


15,085.85 


17,105.46 


6,425.41 


16,497.84 


14,018 75 


7,357.31 


81,201.84 


8,376.88 


4,871.83 


7,017.93 


1,057.66 


7,032.15 


2,899.48 




111,426.44 


25,677.14 




2,320.12 


704.24 


3,932.32 










16,917.73 


7,357.31 


192,628.28 


34,054.02 


4,871.83 


9,338.05 


1,761.90 


10,964.47 


67,482.51 


49,270.14 


388,498.19 


64,650.51 


30,871.65 


45,338.13 


10,653.29 


35,958.55 


46.4 


74.9 


19.5 


13.7 


53.1 


52.9 


41.9 


31.7 



322 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



GEORGIAN BAY 
SYSTEM— Continued 





Chats- 
worth 

272 


Chesley 
1,789 


Coldwater 
626 


Colling- 
wood 
5,783 


Cooks- 
town 
P.V. 


Assets 


$ c. 
221.00 


$ c. 

' ' 595 . 98 
19,892.45 


$ c. 
275.00 


$ c. 
15,950.08 
11,203.24 
47,964.46 


$ c. 
60 00 


Substation equipment 


392 95 


Distribution sustem — overhead . . . 
Distribution system — underground 


4,560.47 


7,675.00 


9,131.52 


1,531.99 

1,377.30 

529.17 


6,781.32 
6,714.58 
1,173.68 


2,779.67 

2,932.65 

440.68 


17,011.28 

22,144.71 

2,876.90 


2,192.62 

2,117.12 

694.21 


Meters 


Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


385.90 


3,264.32 


173.52 


6,165.17 


1,520.03 


Old plant 




5,503.60 








Other plants not distributed 






















Total plant 


8,605.83 
2,403.79 


43,925.93 

15.00 

10,000.00 

2,652.17 

265.49 


14,276.52 

1,544.09 

4,000.00 

801.92 


123,315.84 

100.00 

27,000.00 

1,743.73 

399.06 


16.108.45 




3,005.03 






374.06 

4.90 

3,234.69 

2,277.29 


896 20 




17.34 


Sinking fund on local debentures. . 

Equity in H-E.P.C. systems 

Other assets 






18,843.00 


7,205.13 


80,932.71 


2,675.43 
















16,900.56 


75,701.59 


27,827.66 


233,491.34 


22,702.45 


Deficit 
















Total 


16,900.56 


75,701.59 


27,827.66 


233,491.34 


22,702.45 






Liabilities 


4,600.09 
142.95 


5,030.54 

3.40 

1,850.60 


3,630.30 
466.72 




6,556.37 










7,285.52 
1,768.70 








64.00 












Total liabilities 


4,743.04 


6,884.54 


4,161.02 


9,054.22 


6,556.37 






Reserves 

For equity in H-E.P.C. systems. . . 


2,277.29 
2,786.38 


18,843.00 
13,810.48 


7,205.13 
6,947.36 


80,932.71 
40,788.04 


2,675.43 
5,834.73 








5,063.67 










Total reserves 


32,653.48 


14,152.49 


121,720.75 


8,510.16 






Surplus 


799.91 
3,234.69 
3,059.25 


22,469.46 


3,369.70 


42,604.59 


6,943.63 


Local sinking fund 

Operating surplus 




13,694.11 


6,144.45 


60,111.78 


692.29 






Total surplus 


7,093.85 


36,163.57 


9,514.15 


102,716.37 


7,635.92 






Total liabilities, reserves and surplus 


16,900.56 


75,701.59 


27,827.66 


233,491.34 


22,702.45 


Percentage of net debt to total assets 


13.2 


12.1 


20.2 


5.9 


32.7 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



323 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



Creemore 

587 


Dundalk 
647 


Durham 
1,800 


Elmvale 
P.V. 


Elmwood 
P.V. 


Flesherton 
491 


Grand 

Valley 

587 


Graven- 
hurst 
1,830 






56.59 

546.02 

21,672.38 


106.25 

2,273.07 
8,248.86 






36.50 


3,526.17 










5,293.35 


7,291.01 


7,715.03 


4,812.76 


5,446.88 


11,341.14 


25,813.61 


3,171.36 

2,955.37 

295.27 


3,435.53 
2,494.99 
1,082.10 


6,890.62 
6,873.66 
1,381.46 


3,959.64 

3,254.07 

447.17 


803.88 
992 . 73 
302.28 


1,802.52 

2,183.55 

720.51 


2,179.63 

2,724.23 
503.83 


7,330.04 
9,033.70 
3,904.71 


279.27 


416.38 


1,693.58 


542.13 


1,093.62 


934.82 


205 . 70 


2,062.32 


3,433.74 


380.94 


2,091.39 








919.85 


28,055.29 




























17,426.02 
288 . 76 


15,524.97 

229.70 

3,000.00 

38.05 

39.78 


41,205.70 


18,831.19 
3,204.44 


8,005.27 
1,419.21 


11,088.28 
2,828.68 


17,910.88 

997.89 

2,128.60 
1,051.91 


85,019.19 
1,703.49 




8,000.00 
2,177.12 
' 56.47 




508.76 
10.20 


714.99 


602.37 

8.10 

386.40 

2,053.66 


246.04 
19.40 


6,428.32 
672.99 








7,875.98 


6,686.98 


6,385.69 


17,853.68 


8,963.33 


3,628.75 


6,573.09 


11,934.82 


















24,920 7? 


25,218.19 


69,292.97 


31,713.95 


12,475.01 


17,811.15 


28,662.37 


113,634.79 


















24,920.72 


25,218.19 


69,292.97 


31,713.95 


12,475.01 


17,811.15 


28,662.37 


113,634.79 


534.79 
1,611.99 


774.06 
38.05 


3,243.19 

119.10 

1,122.31 


3,236.60 
455.36 


2,617.46 


3,716.89 
66.39 


2,563.49 
30.56 


10,815.64 
4,371.58 






































2,146.78 


812.11 


4,484.60 


3,691.96 


2,617.46 


3,783.28 


2,594.05 


15,187.22 


6,686.98 
3,195.79 


6,385.69 
3,914.14 


17,853.68 
10,294.40 


8,963.33 
6,646.79 


2,053.66 
2,740.38 


3,628.75 
3,652.07 


6,573.09 
5,220.18 


11,934.82 

16,984.02 

725.00 


















9,882.77 


10,299.83 


28,148.08 


15,610.12 


4,794.04 


7,280.82 


11,793.27 


29,643.84 


5,965.21 


5,562.84 


22,556.81 


3,763.40 


4,582.54 

386.40 

94.57 


2,983.11 


8,436.51 


53,152.77 
7,875.98 


6,925.96 


8,543.41 


14,103.48 


8,648.47 


3,763.94 


5,838.54 


7,774.98 


12,891.17 


14,106.25 


36,660.29 


12,411.87 


5,063.51 


6,747.05 


14,275.05 


68,803.73 


24,920.72 


25,218.19 


69,292.97 


31,713.95 


12,475.01 


17,811.15 


28,662.37 


113,634.79 


11.8 


4.3 


8.7 


16.2 


22.2 


26.7 


11.7 


14.9 



324 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



GEORGIAN BAY 

SYSTEM— Continued 



Municipality 


Hanover 
3,036 


Holstein 
P.V 


Huntsville 
2,507 


Kincardine 
2,429 


Kirkfield 


Population 


P.Y. 






Assets 

Lands and buildings 

Substation equipment 

Distribution system — overhead. . . 
Distribution system — underground 

Line transformers 

Meters 

Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


$ c. 

3,001.32 

9,271.19 

48,940.62 


$ c. 


$ c. 

353.52 

647.30 

13,139.83 


$ c. 

6,389.46 

2,794.20 

42,159.41 


$ c. 






2,102.68 


5,113.67 


17,109.90 

15,506.91 

2,326.30 


571.82 
514.82 
168.69 


6,767.62 
8,673.71 
2,262.52 


10,712.42 

10,492.19 

5,200.12 


557.90 
701.85 
379.00 


5,267.64 


205.93 


566.45 


5,320.59 


301.53 


Old plant . ... 


2,370.91 




5,436.20 






Other plants not distributed 




















Total plant 


103,794.79 

1,582.81 

26,699.39 

2,542.84 

114.36 


3,563.94 
380.24 


37,847.15 

3,883.45 

13,000.00 

1,480.61 

2,064.60 


83,068.39 
50.00 


7,053.95 


Bank and cash balance 

Securities and investments 


294.05 


Accounts receivable 

Inventories 


136.07 

67.87 


590.42 
1,243.31 


936.81 


Sinkinf fund on local debentures. . 




Equity in H-E.P.C. systems 

Other assets 


45,822.14 


2,093.02 


30,684.78 


18,529.52 
111.54 


1,744.11 












Total assets 


180,556.33 


6,241.14 
4,665.82 


88,960.59 


103,593.18 


10,028.92 


Deficit 


1,339.48 












Total 


180,556.33 


10,906.96 


88,960.59 


103,593.18 


11,368.40 






Liabilities 

Debenture balance . . 


33,987.83 
54.57 


225.54 
4,927.71 


2,393.71 
3,059.92 


31,103.03 

1,896.96 

297.79 


2,572.46 


Accounts payable 


1,620.22 


Bank overdraft 




Other liabilities 






544.50 














Total liabilities 


34,042.40 


5,153.25 


5,998.13 


33,297.78 


4,192.68 






Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


45,822.14 
36,590.63 


2,093.02 
1,124.18 


30,684.78 
12,125.08 


18,529.52 
15,626.77 


1,744.11 
2,004.07 


Other reserves. . 
















Total reserves . . 


82,412.77 


3,217.20 


42,809.86 


34,156.29 


3,748.18 






Surplus 

Debentures paid 


53,512.17 


2,536.51 


18,739.83 


33,096.97 


3,427.54 


Local sinking fund 




Operating surplus. 


10,588.99 




21,412.77 


3,042.14 










Total surplus . 


64,101.16 


2,536.51 


40,152.60 


36,139.11 


3,427.54 






Total liabilities, reserves and surplus 


180,556.33 


10,906.96 


88,960.59 


103,593 . 18 


11,368.40 


Percentage of net debt to total assets 


25.3 


124.2 


10.2 


39.1 


50.6 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



325 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



Lucknow 
1,082 


Markdale 
774 


Meaford 
2,707 


Midland 
6,808 


Mildmay 
694 


Mount 
Forest 
1,821 


Neustadt 
465 


Orange- 
ville 
2,785 


$ c. 


$ c. 


$ c. 

1,104.93 

2,398.85 

30,015.36 


$ c. 
19,983.57 
85,096.20 
93,649.38 


$ c. 
6,001.09 


$ c. 

3,725.00 

686.75 

22,682.88 


$ c. 


$ c. 
2,585.07 




780.80 
10,503.49 




1,169.00 


17,009.20 


9,970.79 


32,266.89 


4,385.00 
4,717.22 
1,391.17 


4,151.74 
3,244.99 
1,314.08 


7,278.23 
7,317.62 
3,215.81 


22,972.26 
36,046.39 
18,712.15 


1,657.05 

2,129.16 

502.80 


6,594.59 
7,294.95 
2,302.55 


3,624.89 

2,017.85 

496.41 


7,922.99 
11,400.36 

7,532.55 


2,322.02 


674.93 


1,987.27 


5,386.19 


836.82 


2,127.00 


1,521.48 


6,243.69 




2,080.65 


3,486.43 




849.00 


3,810.95 


1,097.60 


3,204.99 
























29,824.61 
1,236.22 


22,750.68 

1,110.39 

1,255.13 

936.11 

35.00 


56,804.50 

2,812.48 

16,083.05 

1,780.17 


281,846.14 

75.00 

29,000.00 

19,199.98 

4,127.10 


11,975.92 

1,190.61 

945.94 


49,224.67 


18,729.02 

8.11 

"37.22 
18.20 


72,325.54 
921.53 


4,000.00 

1,386.42 

8.52 


4,000.00 
1,718.29 


2,500.00 

1,814.79 

284.96 










9,186.02 


5,032.19 


12,735.65 


125,095.10 


226.15 


16,380.02 


5,502.73 


21,353.58 


















45,641.79 


31,119.50 


90,215.85 


459,343.32 


14,338.62 


71,322.98 


24,295.28 
16,712.99 


99,200.40 
















45,641.79 


31,119.50 


90,215.85 


459,343.32 


14,338.62 


71,322.98 


41,008.27 


99,200.40 


10,801.77 
67.28 


5,482.32 
738.58 


34,814.09 


29,703.26 

33,883.74 

2,034.42 

772.64 


11,895.23 
85.53 


11,721.92 
250.00 
660.41 


6,741.81 
12,022.60 


7,992.00 
1,021.55 




20.00 


757.89 
















10,869.05 


6,240.90 


35,571.98 


66,394.06 


11,980.76 


12,632.33 


18,764.41 


9,013.55 


9,186.02 
5,268.25 


5,032.19 
4,953.50 


12,735.65 
9,182.03 


125,095.10 
110,915.85 


226.15 
206.00 


16,380.02 
14,338.12 


5,502.73 
6,482.94 


21,353.58 
19,878.88 


















14,454.27 


9.985.69 


21,917.68 


236,010.95 


432.15 


30,718.14 


11,985.67 


41,232.46 


8,921.59 


3,517.68 


14,546.11 


82,366.73 


408.27 


19,236.68 


10,258.19 


27,908.00 


11,396.88 


11,375.23 


18,180.08 


74,571.58 


1,517.44 


8,735.83 




21,046.39 








20,318.47 


14,892.91 


32,726.19 


156,938.31 


1,925.71 


27,972.51 


10,258.19 


48,954.39 


45,641.79 


31,119.50 


90,215.85 


459,343.32 


14,338.62 


71,322.98 


41,008.27 


99,200.40 


29.8 


23.9 


45.9 


19.8 


84.9 


24.9 


99 9 


11.6 



326 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



GEORGIAN BAY 
SYSTEM— Continued 



Municipality 


Owen 
Sound 
12,803 


Paisley 
732 


Penetang- 

uishene 

4,046 


Port 
Elgin 
1,230 


Port 


Population 


McNicoll 
928 






Assets 

Lands and buildings 


$ c. 

25,978.31 

12,919.97 

106,461.46 


$ c. 

' 1 ,933 '. 26 
11,504.45 


$ c. 

2,262.10 

7,076.39 

41,283.35 


$ c. 
111.25 


$ c. 
369 08 


Substation equipment 




Distribution system — overhead . . . 
Distribution system — underground 
Line transformers 


25,301.65 


7,448.38 


46,603.72 
56,436.43 
27,532.69 


1,602.53 
2,930.91 
1,045.51 


15,661.52 

13,754.34 

3,503.33 


5,335.48 
6,039.69 
2,057.10 


1,322.48 


Meters 


2,497.83 


Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 

Steam or hydraulic plant 

Old plant 


422.33 


3,879.83 
33,282.00 


885.45 


1,530.00 


759.34 


659 . 19 


1,745.00 




4,213.00 




Other plants not distributed 




















Total plant. . 


313,094.41 
688.88 


21,647.11 

609.71 

2,500.00 

506.94 


85,071.03 


43,817.51 

5,394.35 

7,500.00 

695 . 24 

27.64 


12,719.29 


Bank and cash balance 


78.99 


Securities and investments 


1,152.98 

6,992.36 

467.76 




Accounts receivable 


17,691.85 
10,699.29 


306.22 


Inventories 


11.70 


Sinking fund on local debentures. . 






Equity in H-E.P.C. systems 

Other assets 


101,536.38 


5,273.82 


36,078.52 


1,938.03 


3,328.98 














Total assets 


443,710.81 


30,537.58 


129,762.65 


59,372.77 


16,445.18 


Deficit 
















Total 


443,710.81 


30,537.58 


129,762.65 


59,372.77 


16,445.18 






Liabilities 

Debenture balance 




10,091.92 
17.50 


15,587.71 
7,335.47 
2,386.80 


37,995.69 
4,498.92 


2,070.25 


Accounts payable 


1.00 
4,098.74 
2,667.72 


677.47 


Bank overdraft 




Other liabilities 




20.00 












Total liabilities 


6,767.46 


10,109.42 


25,309.98 


42,514.61 


2,747.72 






Reserves 

For equity in H-E.P.C. systems . . . 
For depreciation 


101,536.38 
59,025.51 


5,273.82 
3,623.07 


36,078.52 
31,117.49 


1,938.03 
2,184.18 


3,328.98 
4,101.83 


Other reserves 
















Total reserves 


160,561.89 


8,896.89 


67,196.01 


4,122.21 


7,430.81 






Surplus 

Debentures paid 

Local sinking fund 


141,000.00 


5,908.08 


25,412.29 


4,004.31 


5,229.75 


Operating surplus 


135,381.46 


5,623.19 


11,844.37 


8,731.64 


1,036.90 






Total surplus 


276,381.46 


11,531.27 


37,256.66 


12,735.95 


6,266.65 


Total liabilities, reserves and surplus 


443,710.81 


30,537.58 


129,762.65 


59,372.77 


16,445.18 


Percentage of net debt to total assets 


1.9 


40.0 


27.0 


74.0 


20.9 



934 



HYDRO-ELECTRIC POWER COMMISSION 



327 



' 'A"- Continued 

Hydro Municipalities as at December 31, 1933 



Port Perry 
1,130 


Priceville 
P.V. 


Ripley 
451 


Rosseau 

251 


Shelburne 
1,064 


Southamp- 
ton 
1,520 


Stayner 
1,042 


Sunderland 
P.V. 


$ c. 


$ c. 
68.00 


$ c. 


$ c. 


$ c. 

800.00 

566.60 

14,735.46 


$ c. 
25.00 


$ c. 


$ c. 


2 564 65 






200.00 

12,527.17 




18,957.29 


4,661.78 


9,975.19 


7,102.01 


19,252.84 


4,158.87 


4,391.61 
3,990.22 
1,037.90 


702.86 
380.00 
139.88 


3,540.24 

1,434.83 

844.33 


2,204.63 

1,032.67 

436.95 


6,215.47 
6,411.08 
1,059.60 


5,833.56 
6,964.94 
1,958.73 


5,380.00 

5,227.20 

966.80 


1,365.63 

1,998.01 

627.74 


176.42 


833.90 


1,164.99 


1,126.07 


2,273.26 


1,276.60 


326.63 


178.02 










739.50 


2,077.00 


4,132.41 


2,030.00 




























31,118.09 
1,589.23 


6,786.42 
139.92 


16,959.58 
1,127.09 


11,902.33 
752.99 


32,800.97 


37,388.67 
2,549.49 


28,760.21 

444 . 79 

4,000.00 

664.40 


10,358.27 
1,965.18 


10,000.00 


5,000.00 

726.63 

82.19 


1,000.00 


619.41 
46.41 


54.34 
4.08 


413.09 
• 22.34 


1,505.29 


1,344.96 
23.15 


374.90 
9.39 










7,789.28 


838.98 


3,882.39 


790.05 


10,112.03 


1,993 07 


8,696.77 


6,183.71 


















51,162.42 


7,823.74 
6,995.38 


22,404.49 


14,950.66 


48,721.82 


43,299.34 


42,566.17 


19,891.45 
















51,162.42 


14,819.12 


22,404.49 


14,950.66 


48,721.82 


43,299.34 


42,566.17 


19,891.45 


14,961.30 
5.38 


2,920.31 
5,384.44 


10,389.37 
43.15 


13,000.00 
19.15 


4,306.73 

1,283.26 

238.54 


24,930.96 
332.60 


1,165.63 
706.76 


3,006.79 
2,156.84 


273.99 




70.00 






25.00 
















15,240.67 


8,304.75 


10,502.52 


13,019.15 


5,828.53 


25,263.56 


1,897.39 


5,163.63 


7,789.28 
5,827.11 


838.98 
1,595.70 


3,882.39 
3,127.76 


790.05 
492.47 
648.99 


10,112.03 
10,273.07 


1,993.07 
1,847.00 


8,696.77 
9,032.87 


6,183.71 
3,176.56 
















13,616.39 


2,434.68 


7,010.15 


1,931.51 


20,385.10 


3,840.07 


17,729.64 


9,360.27 


4,920.36 


4,079.69 


3,582.57 




15,613.27 


8,069.04 


12,834.37 


3,793.21 








17,385.00 




1,309.25 




6,894.92 


6,126.67 


10,104.77 


1,574 34 










22,305.36 


4,079.69 


4,891.82 




22,508.19 


14,195.71 


22,939.14 


5,367.55 








51,162.42 


14,819.12 


22,404.49 


14,950.66 


48,721.82 


43,299.34 


42,566.17 


19,891.45 


35.1 


118.9 


56.8 


91.9 


15.1 


61.1 


5.6 


37.7 



328 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



GEORGIAN BAY 
SYSTEM— Continued 



Municipality 


Tara 
491 


Teeswater 
805 


Thornton 
P.V. 


Tottenham 
546 


Uxbridge 
1,506 


Population 




Assets 

Lands and buildings 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 
40 00 


Substation equipment 




330.31 
16,987.54 




358.50 
8,055.08 


2,657 65 


Distribution system — overhead . . . 
Distribution system — underground 

Line transformers 

Meters 

Street light equipment, regular. . . . 


10,999.17 

2,176.95 

1,719.24 

430.59 


6,403.82 


13,388.67 


4,746.02 
3,315.65 
1,406.90 


860.41 
796.76 
381.95 


1,117.48 

2,109.02 

460.17 


3,875.43 
4,475.05 
1,259.64 


Street light equipment, ornamental 


1,269.05 




Miscellaneous construction expense 
Steam or hydraulic plant 


1,907.49 


300.35 


1,265.68 


910.15 






Old plant 




4,976.86 




286.45 




Other plants not distributed 




















Total plant 

Bank and cash balance. . 


16,595.00 
1,530.50 


33,670.77 

558.28 

3,000.00 

348.96 


8,743.29 
396.61 


13,652.38 
448.48 


26,606.59 


Securities and investments. . 


8,000.00 


Accounts receivable 

Inventories 


289.00 
61.20 


323.16 


987.60 

24.48 


1,033.14 
6.12 


Sinking fund on local debentures 








Equity in H-E.P.C. systems 

Other assets 


4,661.32 


6,444 . 10 


1,777.80 


5,592.84 


8,297.67 














Total assets 


23,137.02 
3,001.19 


44,022.11 


11,240.86 
4,362.14 


20,705.78 
3,108.43 


43,943.52 


Deficit 








Total 


26,138.21 


44,022.11 


15,603.00 


23,814.21 


43,943.52 






Liabilities 

Debenture balance 

Accounts payable 

Bank overdraft 


5,497.64 
38.25 


12,157.05 
3,847.88 


3,389.31 
2,604.20 


7,629.59 
498.99 


11,860.05 
658 '. 19 


Other liabilities 




4.00 




154.06 


5.00 










Total liabilities 


5,535.89 


16,008.93 


5,993.51 


8,282.64 


12,523.24 






Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


4,661.32 
5,938.64 


6,444.10 
4,406.16 


1,777.80 
3,721.00 


5,592.84 
4,601.22 


8,297.67 
4,553.14 


Other reserves. . 
















Total reserves 


10,599.96 


10,850.26 


5,498.80 


10,194.06 


12,850.81 






Surplus 

Debentures paid 

Local sinking fund 


10,002.36 


15,842.95 


4,110.69 


5,337.51 


4,347.54 


Operating surplus 




1,319.97 






14,221.93 












Total surplus 


10,002.36 


17,162.92 


4,110.69 


5,337.51 


18,569.47 


Total liabilities, reserves and surplus 


26,138.21 


44,022.11 


15,603.00 


23,814.21 


43,943.52 


Percentage of net debt to total assets 


30.0 


42.6 


63.3 


54.8 


35.1 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



329 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



Victoria 

Harbor 

1,171 


Walkerton 
2,340 


Waubau- 
shene 
P.V. 


Wiarton 
1,911 


Winder- 
mere 
135 


Wingham 
1,842 


Woodville 
414 


GEORGIAN 

BAY 

SYSTEM 

SUMMARY 


$ c 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 

9,163.34 

4,863.91 

40,474.75 


$ c. 
2,970.40 


$ c. 
110,690.15 












173,392.17 


8,616.56 


39,551.62 


6,129.60 


21,291.32 


9,169.96 


1,146,338.42 
66,437.67 


1,278.18 

2,252.25 

366.32 


10,638.64 

10,475.11 

2,276.74 


1,556.06 

1,810.39 

221.79 


5,554.58 
5,780.34 
1,950.58 


2,852.40 
865.05 
247.26 


15,635.95 

14,188.17 

3,371.64 


2,127.54 
2,116.14 

217.55 


378,217.38 
401,981.17 
132,759.04 


667.12 


1,984.43 


370.39 


5,001.65 


354.57 


4,930.59 
14,711.99 
12,320.02 


275.21 


103,402.25 
47,993 99 




5,238.00 




3,981.00 




2,182.50 


165,592.50 
























13,180.43 
328.50 


70,164.54 
4,198.07 


10,088.23 
1,911.68 


43,559.47 
2,402.59 


13,489.24 
10.00 


119,660.36 

30.00 
9,000.00 
1,250.88 
5,671.97 


9,889.34 

546.85 

5,000.00 

895.27 


2,726,804.74 

68,376.93 
218,145.77 


514.38 
16.32 


1,878.86 
578.52 


255.78 
.22.00 


457.08 
31.96 


1,367.46 


117,057.09 
27,596 75 








11,497 07 


3,642.44 


3,921.66 


2,070.83 


3,047.88 


722.32 


18,287.75 


6,229.56 


863,259.30 
111 54 


















17,682.07 


80,741.65 


14,348.52 


49,498.98 


15,589.02 


153,900.96 


22,561.02 


4,032,849.19 
53,290.45 


















17,682.07 


80,741.65 


14,348.52 


49,498.98 


15,589.02 


153,900.96 


22,561.02 


4,086,139.64 


1,004.26 
49.96 


59,094.17 

25.88 


559.40 
13.30 


36,268.93 
331.12 


4,530.68 

8,378.61 

188.38 

345.00 


35,153.07 


2,868.88 

75.77 


672,671 .15 

144,632.18 




2,234.15 
444.77 


23,493 67 




5.00 




5.00 




8,526 57 










1,054.22 


59,125.05 


572.70 


36,605.05 


13,442.67 


37,831.99 


2,944.65 


849,323.57 


3,642.44 
3,758.26 


3,921.66 
2,630.78 


2,070.83 
2,177.94 


3,047.88 
2,014.94 


722.32 
883 . 88 
189.57 


18,287.75 
22,444.34 


6,229.56 
2,077.27 


863,259.30 

674,284.37 

2 663 56 
















7,400.70 


6,552.44 


4,248.77 


5,062.82 


1,795.77 


40,732.09 


8,306.83 


1,540,207.23 


5,495.74 


3,905.83 


2,940.60 


1,131.07 




60,952.43 


2,631.12 


943,745.38 






11,497 07 


3,731.41 


11,158.33 


6,586.45 


6,700.04 


350.58 


14,384.45 


8,678.42 


741,366.39 


9,227.15 


15,064.16 


9,527.05 


7,831.11 


350.58 


75,336.88 


11,309.54 


1,696,608.84 


17,682.07 


80,741.65 


14,348.52 


49,498.98 


15,589.02 


153,900.96 


22,561.02 


4,086,139.64 


7.5 


77.0 


4.7 


78.8 


90.4 


28.0 


18.0 


26.4 



330 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



EASTERN ONTARIO 
SYSTEM 


Municipality 


Alexandria 
2,340 


Apple Hill 
P.V. 


Athens 
582 


Bath 

350 


Belleville 


Population 


14,059 






Assets 

Lands and buildings 


$ c. 


$ c. 
169.06 


$ c. 


$ c. 


$ c. 
36,108.70 


Substation equipment 








2,338.65 


Distribution system — overhead . . . 
Distribution system — underground 
Line transformers 


27,957.65 


2,886.41 


13,951.89 


5,819.73 


105,110.27 


8,080.79 
6,909.32 
2,224.20 


1,288.37 

1,000.21 

421.12 


1,757.05 

2,479.53 

698.90 


1,011.93 
676.87 
554.37 


23,330.54 


Meters 


55,180.56 


Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


17,220.75 


5,122.65 


210.33 


1,011.61 


727.38 


5,601.97 


Old plant 


4,466.89 


709.55 








Other plants not distributed. ..... 




















Total plant 


54,761.50 

2,611.41 
7,000.00 
1,876.12 


6,685.05 
282.51 


19,898.98 
1,152.51 


8,790.28 
11.76 


244,891.44 


Bank and cash balance 


17,671.22 


Securities and investments 


5,000.00 


Accounts receivable 


143.53 


2,069.44 


666.78 


15,601.29 


Inventories 


7,079.79 


Sinking fund on local debentures. . 












Equity in H-E.P.C. systems 

Other assets 


17,415.16 


1,689.16 


2,458.42 


418.12 


59,864.19 














Total assets 


83,664.19 


8,800.25 
323.54 


25,579.35 


9,886.94 


350,107.93 


Deficit 














Total 


83,664.19 


9,123.79 


25,579.35 


9,886.94 


350,107.93 






Liabilities 

Debenture balance 


19,798.16 
3,571.45 


3,348.68 
106.37 


11,759.10 


7,284.91 
1,605.84 


52,000.00 


Accounts payable 




Bank overdraft 






Other liabilities. . 


466.23 






22.00 


5,443.34 










Total liabilities 


23,835.84 


3,455.05 


11,759.10 


8,912.75 


57,443.34 






Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


17,415.16 
10,513.76 


1,689.16 
1,328.26 


2,458.42 
1,952.75 


418.12 
322.00 


59,864.19 
20,090.75 


Other reserves 


1,177.47 














Total reserves 


27,928.92 


3,017.42 


4,411.17 


740.12 


81,132.41 


Surplus 

Debentures paid 


28,335.68 


2,651.32 


2,240 90 


215.09 


124,000.00 


Local sinking fund . . 




Operating surplus 


3,563.75 




7,168.18 


18.98 


87,532.18 






Total surplus 


31,899.43 


2,651.32 


9,409.08 


234.07 


211,532.18 


Total liabilities, reserves and surplus 


83,664.19 


9,123.79 


25,579.35 


9,886.94 


350,107.93 


Percentage of net debt to total assets 


35.9 


48.6 


50.9 


95.2 


19.8 



934 



HYDRO-ELECTRIC POWER COMMISSION 



33 



4 *A"— Continued 

Hydro Municipalities as at December 31, 1933 



Bloomfield 
614 


Bowman- 
ville 
3,641 


Brighton 
1,413 


Brockville 
9,615 


Cardinal 
1,305 


Carleton 
Place 

4,272 


Chesterville 
950 


$ c. 


$ c. 


$ c. 


$ c. 

45,295.14 

1,000.87 

83,857.03 


$ c. 


$ c. 

6,255.32 

2,471.63 

41,145.03 


$ c. 
250.00 


410.00 










11,144.26 


43,954.11 


14,379.75 


10,811.54 


7,946.71 


2,230.77 

2,677.82 

908 . 20 


7,599.91 

17,014.21 

2,860.10 


3,965.45 

6,449 . 20 

821.98 


35,877.33 
42,945.18 
20,434.12 


2,580.91 

2,214.16 

385.27 


10,331.16 

16,599.67 

6,758.16 


3,245.64 

4,112.97 

526.97 


1,403.42 


2,406.53 


236.73 


3,044.90 

54,961.03 

4,821.76 


759.18 


3,580.79 


658.68 








3,474.80 


5,293.19 


























18,774.47 


73,834.86 
11,528.65 


25,853.11 
25.00 


292,237.36 

783.90 

135,000.00 

9,682.82 

2,385.49 


20,225.86 
1,183.57 


92,434.95 

4,319.40 

19,000.00 

5,200.34 

892.06 


16,740.97 
585.95 




9,000.00 


235.33 


4,684.85 
3,046.76 


4,915.73 
4,194.51 


39.00 


723.03 
608 . 79 








2,562.61 


11,113.91 


3,884.81 


90,546.25 


1,431.50 


40,058.83 


17,050.69 
















21,572.41 


104,209.03 


38,873.16 


530,635.82 


22,879.93 


161,905.58 


44,709.43 
















21,572.41 


104,209.03 


38,873.16 


530,635.82 


22,879.93 


161,905.58 


44,709.43 


7,202.16 


66,486.12 


22,558.84 

5.21 

2,687.69 

78.00 




13,569.91 
179.43 


43,641.56 


1,124.18 


979.35 


13,877.20 

5,898.12 

47.00 


5.40 


4.89 






12.00 


560.53 




718.73 










8,198.40 


67,046.65 


25,329.74 


19,822.32 


13,749.34 


44,360.29 


1,129.58 


2,562.61 
3,970.96 


11,113.91 
3,261.50 


3,884.81 
1,694.13 


90,546.25 

73,525.48 

6,497.60 


1,431.50 
982.00 


40,058.83 

10,431.10 

1,500.00 


17,050.69 
7,559.10 










6,533.57 


14,375.41 


5,578.94 


170,569.33 


2,413.50 


51,989.93 


24,609.79 


3,997.84 


4,513.88 


2,441.16 


226,657.54 


1,430.09 


22,358.44 


5,375.82 


2,842.60 


18,273.09 


5,523.32 


113,586.63 


5,287.00 


43,196.92 


13,594.24 


6,840.44 


22,786.97 


7,964.48 


340,244.17 


6,717.09 


65,555.36 


18,970.06 


21,572.41 


104,209.03 


38,873.16 


530,635.82 


22,879.93 


161,905.58 


44,709.43 


43.1 


72.0 


72.4 


4.5 


64.1 


36.4 


4.1 



332 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



EASTERN ONTARIO 
SYSTEM— Continued 



Municipality 


Cobourg 
5,619 


Colborne 
977 


Deseronto 
1,418 


Finch 
383 


Hastings 
707 


Population 






Assets 

Lands and buildings 


$ c. 


$ c. 


$ c. 


$ c. 


$ c. 


Substation equipment 






161.18 
9,700.34 






Distribution system — overhead . . . 
Distribution system — underground 

Line transformers 

Meters 

Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


62,880.91 


6,037.64 


7,414.99 


14,011.23 


15,854.62 

22,307.76 

8,391.51 


670.66 
1,390.75 
1,321.40 


1,442.62 

4,771.27 

432.60 


1,393.35 

1,728.20 

435.62 


1,771.80 
2,901.40 
1,160.09 


4,574.24 


2,463.34 


305.94 


23.24 


716.28 


Old plant 










1,733.13 


Other plants not distributed 
























Total plant 


114,009.04 
17,960.58 


11,883.79 
1,956.52 


16,813.95 
3,436.29 


10,995.40 

108.70 

3,000.00 

121.29 


22,293.93 


Bank and cash balance 


586.86 


Securities and investments 


5,000.00 


Accounts receivable 

Inventories 


5,180.48 
3,834.53 


156.91 
538.05 


691.22 
721.46 


554.44 


Sinking fund on local debentures. . 






Equity in H-E.P.C. systems 

Other assets 


8,067.27 


337.09 


1,951.46 


1,781.86 


788.72 














Total assets 


149,051.90 


14,872.36 


23,614.38 


16,007.25 


29,223.95 


Deficit 
















Total 


149,051.90 


14,872.36 


23,614.38 


16,007.25 


29,223.95 






Liabilities 

Debenture balance 


102,702.35 
4,884.99 


12,194.59 
45.56 


11,847.71 
468.54 


5,672.68 
707.11 


19,762.33 


Accounts payable 


13.80 


Bank overdraft 




Other liabilities 


3,462.03 


196.24 


192.12 




30.00 








Total liabilities 


111,049.37 


12,436.39 


12,508.37 


6,379.79 


19,806.13 






Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


8,067.27 
3,833.12 


337.09 
188.00 


1,951.46 
920.92 


1,781.86 
1,138.00 


788.72 
1,011.60 


Other reserves. . 
















Total reserves 


11,900.39 


525.09 


2,872.38 


2,919.86 


1,800.32 






Surplus 

Debentures paid 


3,291.15 




3,152.29 


1,327.32 


1,237.67 


Local sinking fund . . . 






Operating surplus 


22,810.99 


1,910.88 


5,081.34 


5,380.28 


6,379.83 






Total surplus 


26,102.14 


1,910.88 


8,233.63 


6,707.60 


7,617.50 






Total liabilities, reserves and surplus 


149,051.90 


14,872.36 


23,614.38 


16,007.25 


29,223.95 


Percentage of net debt to total assets 


78.8 


85.5 


57.7 


44.8 


69.6 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



333 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



Havelock 
1,096 


Kemptville 
1,227 


Kingston 
23,260 


Lakefield 
1,303 


Lanark 
636 


Lancaster 
601 


Lindsay 
7,109 


$ c. 


$ c. 


$ c. 

184,945.77 

45,599.79 

165,930.10 

149,557.13 

58,020.14 

99,915.93 

71,262.59 


$ c. 
3,137.97 


$ c. 


$ c. 


$ c. 
10,556.68 


572 90 








3,176.56 


19,583.50 


19,755.54 


21,813.53 


6,201.44 


6,402.26 


71,574.10 


2,259.82 
5,387.88 
1,842.33 


5,888.74 
6,490.65 
1,063.16 


5,101.95 
7,070.99 
1,876.16 


1,134.89 

1,796.99 

682.38 


962.35 

1,433.52 

650.65 


20,920.49 
30,341.01 
10,291.48 


4,409.17 


6,067.28 


46,345.74 


3,815.70 


330.38 


1,068.55 


1,608.54 


2,420.45 




15,890.14 


3,445.25 






























36,476.05 

2,789.27 
7,000.00 


39,265.37 

760.85 

20,000.00 

3,116.38 

998.53 


837,467.33 

65,301.65 

172,175.00 

36,132.75 

9,806.07 

32,697.13 

1,000.00 


46,261.55 

479.65 

10,000.00 

1,270.74 


10,146.08 

711.41 

1,982.05 

203.48 


10,517.33 
357.04 


148,468.86 

8,431.77 
46,500.00 


262.62 


452.20 


4,918.05 
424.76 












5,666.80 


9,967.75 


4,814.31 
9.74 


3,115.98 


4,203 . 18 


34,998.34 












52,194.74 


74,108.88 


1,154,579.93 


62,835.99 


16,159.00 


15,529.75 
6,261.95 


243,741.78 














52,194.74 


74,108.88 


1,154,579.93 


62,835.99 


16,159.00 


21,791.70 


243,741.78 


16,437.62 
63.08 


18,271.25 
2,208.15 


104,430.01 
6,361.67 


25,935.95 
700.00 


3,433.99 

24.35 


3,297.41 
5,129.50 


108,275.79 
19.56 






640.96 


360.96 




73.50 


1,753.18 










16,500.70 


20,479.40 


111,432.64 


26,996.91 


3,458.34 


8,500.41 


110,048.53 




9,967.75 

6,873.22 




9,728.63 


1,763.25 


2,415.10 




7,112.47 


127,490.12 
161,795.63 


16,765.26 














12,779.27 


16,840.97 


289,285.75 


14,542.94 


4,879.23 


6,618.28 


51,763.60 


16,462.38 


6,728.75 


207,469.99 

32,697.13 

513,694.42 


7,564.05 


4,127.48 


6,673.01 


21,724.21 


6,452.39 


30,059.76 


13,732.09 


3,693.95 




60,205.44 








22,914.77 


36,788.51 


753,861.54 


21,296.14 


7,821.43 


6,673.01 


81,929.65 


52,194.74 


74,108.88 


1,154,579.93 


62,835.99 


16,159.00 


21,791.70 


243,741.78 


35.5 


31.9 


7.0 


46.5 


26.5 


75.0 


52.7 



334 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



EASTERN ONTARIO 
SYSTEM— Continued 



Municipality 

Population 


Madoc 
1,059 


Marmora 
924 


Martintown 
P.V. 


Maxville 
785 






Assets 

Lands and buildings 

Substation equipment 


$ c. 
100.00 


$ c. 


$ c. 
126.15 


$ c. 




407 79 


Distribution system — overhead. . . . 
Distribution system — underground 
Line transformers 


9,680.27 


12,591.18 


2,709.88 


11,463.57 


2,351.64 
4,786.31 
1,500.00 


2,378.99 
3,395.91 
1,088.59 


690.33 
871.51 
335.26 


1,540.96 


Meters 

Street light equipment, regular. . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


2,465.30 
1,605.64 


225.89 


2,000.91 


653.27 


2,402.45 


Old plant 




573.62 






Other plants not distributed 


















Total plant 


18,644.11 
2,485.58 


22,029.20 

4,321.14 
657.33 
588.08 


5,386.40 

965 . 74 

1,000.00 

248.46 


19,885.71 
601.47 




Securities and investments 




Accounts receivable 

Inventories 


421.49 


224.46 


Sinking fund on local debentures. . . 










Equity in H-E.P.C. systems 

Other assets 


2,479.40 


2,136.48 


1,082.90 


5,041.29 












Total assets 


24,030.58 


29,732.23 


8,683.50 


25,752.93 


Deficit 














Total 


24,030.58 


29,732.23 


8,683.50 


25,752.93 






Liabilities 

Debenture balance 

Accounts payable 


963.20 
51.00 


7,735.98 
4.18 


1,961.14 


7,608.74 
1.37 


Bank overdraft . . 






Other liabilities 




10.00 




80.00 










Total liabilities 


1,014.20 


7,750.16 


1,961.14 


7,690.11 






Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


2,479.40 
921.05 


2,136.48 
4,058.21 


1,082.90 
1,183.37 


5,041.29 
3,701.66 


Other reserves 














Total reserves . 


3,400.45 


6,194.69 


2,266.27 


8,742.95 






Surplus 

Debentures paid . . 


13,036.80 


9,930.13 


4,038.86 


8,391.26 


Local sinking fund. . 




Operating surplus 


6,579.13 


5,857.25 


417.23 


928.61 






Total surplus 


19,615.93 


15,787.38 


4,456.09 


9,319.87 






Total liabilities, reserves and surplus 


24,030.58 


29,732.23 


8,683.50 


25,752.93 


Percentage of net debt to total assets 


4.7 


28.1 


25.8 


37.1 



934 



HYDRO-ELECTRIC POWER COMMISSION 



335 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



Napanee 
3,014 


Norwood 

727 


Omemee 
498 


Oshawa 
23,002 


Ottawa 
130,672 


Perth 
3,994 


Peterborough 
22,809 


$ c. 
2,173.32 


$ c. 


$ c. 


$ c. 
56,776.03 


$ c. 
337,378.21 
700,669.39 
709,461.28 
172,744.02 
303,083.73 
276,306.34 
117,317.59 


$ c. 

6,851.01 

3,932.82 

46,843.70 


$ c. 
75,202.75 




457.53 
23,152.45 


360.32 
10,880.65 


98,652.41 


39,244.37 


183,835.78 


210,098.39 


8,356.22 

16,394.23 

3,814.09 


4,609.18 
4,822.00 
1,848.52 


2,668.47 

2,434.79 

667.86 


40,454.32 
97,743.58 
15,669.64 


22,413.35 

20,967.92 

3,939.32 


95,759.24 
93,552.08 
53,728.00 


2,787.40 


3,939.32 


1,540.92 


6,342.36 


33,115.49 


5,011.75 


53,652.16 




2,447.51 




8,831.65 




23,606.94 


29,771.74 
























72,769.63 
1,934.74 


41,276.51 

3,781.32 

8,000.00 

171.77 


18,553.01 
2,224.49 


409,653.36 
250.00 


2,650,076.05 

2,127.29 
38,000.00 
99,557.41 
22,198.34 
682,182.51 
52,211 78 


133,566.81 

5,472.56 

35,000.00 

4,161.21 

7,663.13 


710,416.77 
330.00 


4,910.96 
5,065.45 


163.22 


57,831.30 
8,574.22 


29,743.35 
5,053.11 








225,737 16 


14,478.29 


2,711.38 




186,135.35 
304.52 


34,151.00 
328.15 


117,464.27 


















99,159.07 


55,940.98 


20,940 7? 


662,748.75 


3,546,353.38 


220,342.86 


1,088,744.66 
















99,159.07 


55,940.98 


20,940.72 


662,748.75 


3,546,353.38 


220,342.86 


1,088,744.66 


35,031 54 


27,760.97 
583.21 


4,003.70 


249,672.23 

24,200.87 

9,831.79 

18,929.21 


923,627.34 

94,965.53 

2,895.07 


55,526.99 
268.59 


527,920.00 
28,249 53 






4,061 57 


532.02 


326.30 


45.00 


1,899.59 


80.00 








35,563.56 


28,670.48 


4,048 . 70 


302,634.10 


1,021,487.94 


57,695.17 


560,311.10 


14,478.29 


2,711.38 
9,011.80 




186,135.35 
37,436.92 
17,405.24 


52,211.78 
930,274.58 
164,586.88 


34,151.00 
34,625.03 


117,464.27 


3,091.42 
2,983.35 


6,047.88 


94,929.86 
9,400 . 20 










20,553.06 


11,723.18 


6,047.88 


240,977.51 


1,147,073.24 


68,776.03 


221,794.33 


34,968.46 


.9,339.03 


7,996.30 


60,327.77 


56,372.66 
682,182.51 
639,237.03 


52,873.01 






225,737.16 


8,073.99 


6,208.29 


2,847.84 


58,809.37 


40,998.65 


80,902.07 


43,042.45 


15,547.32 


10,844.14 


119,137.14 


1,377,792.20 


93,871.66 


306,639.23 


99,159.07 


55,940.98 


20,940.72 


662,748.75 


3,546,353.38 


220,342.86 


1,088,744.66 


42.0 


53.9 


21.8 


63.5 


29.2 


31.0 


44.9 



336 



TWENTY-SIXTH ANNUAL REPORT OB THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



EASTERN ONTARIO 
SYSTEM— Continued 



Alunicipality 


Picton 
3,217 


Port Hope 
4,626 


Prescott 
2,952 


Richmond 
381 


Russell 


Population 


P.V. 






Assets 

Lands and buildings 


$ c. 

7,182.49 

2,004.66 

39,652.20 


$ c. 
4,050.00 


$ c. 
2,761.54 


$ c. 


$ c. 


Substation equipment 






Distribution system — overhead. . . 
Distribution system — underground 
Line transformers 


47,651.69 


38,915.28 


6,127.37 


7,735.81 


12,624.33 

16,740.47 

4,131.66 


11,598.21 

19,384.64 
2,613.82 


13,303.50 

18,431.61 

2,006.66 


769.40 

1,136.31 

173.98 


1,382.48 


Meters 


1,458.78 


Street light equipment, regular . . . 
Street light equipment, ornamental 
Miscellaneous construction expense 
Steam or hydraulic plant 


499.49 


2,621.36 


828.2i 


1,089.63 


612.67 


1,199.88 


Old plant 


3,105.28 





11,808.35 






Other plants not distributed 


















Total plant 


88,062.45 

50.00 

14,000.00 

5,104.68 

3,842.99 


86,126.64 
1,184.05 


88,316.57 

1,031.66 
3,000.00 
1,701.75 


8,819.73 
323.76 


12,276.44 


Bank and cash balance 


1,680.80 


Securities and investments 




Accounts receivable 


3,014 20 
1,060.76 




976.63 


Inventories 






Sinking fund on local debentures. . 








Equity in H-E.P.C. systems 

Other assets 


20,429.65 
997 . 29 


17,960.58 


25,550.45 
106.00 


894.27 


2,863.57 










Total assets 


132,487.06 


109,346.23 
1,046.56 


119,706.43 


10,037.76 


17,797.44 


Deficit 














Total 


132,487.06 


110,392.79 


119,706.43 


10,037.76 


17,797.44 






Liabilities 

Debenture balance 




23,863.83 
4,969.50 




5,504.02 
104.27 


7,211.90 


Accounts payable . . . 


3,279.09 

1,562.86 

978.00 


908 . 69 


251.23 


Bank overdraft .... 




Other liabilities. . 


3 T 110.77 


204.51 


25.50 








Total liabilities 


5,819.95 


31,944.10 


1,113.20 


5,633.79 


7,463.13 






Reserves 

For equity in H-E.P.C. systems . . . 
For depreciation .... 


20,429.65 

11,773.85 
1,458.68 


17,960.58 
5,351.94 


25,550.45 
30,397.84 


894.27 
850.87 


2,863.57 
1,493.98 


Other reserves. . . 














Total reserves 


33,662.18 


23,312.52 


55,948.29 


1,745.14 


4,357.55 






Surplus 

Debentures paid 


5,730.32 


55,136.17 


23,979.34 


995.98 


2,788.10 


Local sinking fund . 




Operating surplus 


87,274.61 




38,665.60 


1,662.85 


3,188.66 








Total surplus. . . 


93,004.93 


55,136.17 


62,644.94 


2,658.83 


5,976.76 






Total liabilities, reserves and surplus 


132,487 06 


110,392.79 


119,706.43 


10,037.76 


17,797.44 


Percentage of net debt to total assets 


5 1 


34.9 


1.2 


61.6 


50.0 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



337 



"A"— Continued 

Hydro Municipalities as at December 31, 1933 



Smiths Falls 
7,501 


Stirling 
865 


Trenton 
6,331 


Tweed 
1,247 


Warkworth 
P.V. 


Wellington 
900 


West port 
733 


$ c. 
19,928.85 


$ c. 
8,410.00 
7,042.12 
5,007.22 


$ c. 

5,114.41 

23,080.03 

87,820.66 


$ c. 


$ c. 


$ c. 

200.00 

499.80 

14,660.44 


$ c. 


4,745.66 








86,143.93 


10,186.86 


5,494.98 


7,155.76 


24,946.41 

32,399.24 

9,295.13 


3,681.12 
4,856.49 
1,054.48 


20,622.75 
25,913.81 
13,556.84 


3,002.41 

4,777.47 
1,035.28 


684.66 

1,510.80 

309.88 


3,703.50 
5,168.68 
1,131.40 


1,001.23 

1,353.44 

526.70 


6,631.95 
38,001.49 


1,097.22 


3,141.03 


345.31 


610.69 


774.55 


1,335.26 


21,513.48 








3,618.02 


2,477.92 


1,713.00 


























243,606.14 

5,131.37 
42,000.00 


31,148.65 

5,231.59 
4,762.73 
1,058.50 
1,090.28 


179,249.53 
11,769.63 


19,347.33 
1,450.81 


12,229.03 

416.85 

2,500.00 

321.22 


28,616.29 

10.00 

5,000.00 

560.52 


13,085.39 
"3,000.00 


4,014.82 
721.28 


7,688.95 
6,300.75 


570.00 
1.197.71 


653.28 










52,428.70 


3,026.08 
50.00 


15,465.69 


2,472.03 


1,484.82 


3,949.61 


949.46 














347,902.31 


46,367.83 


220,474.55 


25,037.88 


16,951.92 


38,136.42 


17,688.13 
















347,902.31 


46,367.83 


220,474.55 


25,037.88 


16,951.92 


38,136.42 


17,688.13 


69,513.40 




154,510.02 


13,061.29 
597.09 


9,401.11 


11,068.35 

739.08 

1,352.82 

2.25 


14,115.96 




1.62 






58.60 


33 


24.00 


2,638.89 


214.69 










69,513.73 


25.62 


157,148.91 


13,873.07 


9,401.11 


13,162.50 


14,174.56 


52,428.70 

62,565.37 

250.00 


3,026.08 
8,672.11 


15,465.69 

6,748.00 

661.84 


2,472.03 
1,956.13 


1,484.82 
1,201.32 


3,949.61 

5,482.78 


949.46 
244.56 














115,244.07 


11,698.19 


22,875.53 


4,428.16 


2,686.14 


9,432.39 


1,194.02 


128,111.60 


10,000.00 


10,489.98 


5,938.71 


1,598.89 


5,931.65 


884.04 


35,032.91 


24,644.02 


29,960.13 


797.94 


3,265.78 


9,609.88 


1,435.51 


163,144.51 


34,644.02 


40,450.11 


6,736.65 


4,864.67 


15,541.53 


2,319.55 


347,902.31 


46,367.83 


220,474.55 


25,037.88 


16,951.92 


38,136.42 


17,688.13 


23.5 


.06 . 


76.7 


61.5 


60.8 


38.5 


85.2 



338 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Balance Sheets of Electrical Departments of 



EASTERN ONTARIO 
SYSTEM— Concluded 



Municipality 


Whitby 
5,294 


Williamsburg 
P.V. 


Winchester 
963 


EASTERN 
ONTARIO 


Population 


SYSTEM 
SUMMARY 






Assets 

Lands and buildings 


$ c 

6,394. It 

34,200.41 

44,799.06 




$ c 


$ c 
299 . 85 


$ c. 

819,667.51 

931,784.52 

2,453,623.17 

322 301 15 


Substation equipment 




Distribution system — overhead. . . 
Distribution system — underground 


2,510. 5£ 


9,529.85 


Line transformers 

Meters 

Street light equipment, regular. . . 
Street light equipment, ornamental 


10,993.72 

14,537.89 

4,567.02 


1,749.87 

1,926.37 

152.11 


2,436.78 

4,904.37 

719.87 


813,528.08 

1,022,036.39 

396,512.94 


Miscellaneous construction expense 
Steam or hydraulic plant 


5,815.00 


50.85 


616.57 


234,934.74 

92,962.52 

154,162.80 


Old plant 


1,340.13 




1,100.00 


Other plants not distributed 














Total plant 


122,647.49 
458.47 


6,389.78 

1,277.70 
4,500.00 
1,620.36 


19,607.29 

1,013.44 

7,000.00 

727.44 


7,241 513 82 


Bank and cash balance 


198 560 93 


Securities and investments 


609,077 11 


Accounts receivable 


4,452.64 
141.87 


329 385 52 


Inventories 


97,440.69 

940,616.80 

923,102.87 

2,795.70 


Sinking fund on local debentures. . 






Equity in H-E.P.C. systems 

Other assets 


20,245.70 


2,473.15 


10,830.56 












Total assets 


147,946.17 


16,260.99 


39,178.73 


10,342,493.44 


Deficit 


7,632.05 












Total 


147,946.17 


16,260.99 


39,178.73 


10,350,125.49 






Liabilities 

Debenture balance 


36,673.08 
45.20 


210.01 
604.59 


6,101.67 
96.72 


2,874,081.77 


Accounts payable 


200,877.92 


Bank overdraft 


28,353.41 


Other liabilities 


768.97 


477.65 


5.00 


44,409.50 






Total liabilities 


37,487.25 


1,292.25 


6,203.39 


3,147,722.60 






Reserves 

For equity in H-E.P.C. systems. . . 
For depreciation 


20,245.70 
16,34261 


2,473.15 
1,788.02 


10,830.56 
6,712.24 


923,102.87 
1,601,734.88 


Other reserves 


367,716.89 












Total reserves 


36,588.31 


4,261.17 


17,542.80 


2,892,554.64 






Surplus 

Debentures paid 


39,939.42 


2,539.99 


4,548.33 


1,259,862.86 


Local sinking fund 




Operating surplus 


33,931.19 


8,167.58 


10,884.21 


2,109,368.59 






Total surplus 


73,870.61 


10,707.57 


15,432.54 


4,309,848.25 






Total liabilities, reserves and surplus 


147,946.17 


16,260.99 


39,178.73 


10,350,125.49 


Percentage of net debt to total assets 


29.3 


9.4 


21.8 


26.0 



1934 



HYDRO-ELFXTRIC POWER COMMISSION 



339 



"A"— Concluded 

Hydro Municipalities as at December 31, 1933 



THUNDER BAY 
SYSTEM 



Fort William 

25,188 


Nipigon 


Port Arthur 
19,749 


THUNDER 

BAY 

SYSTEM 

SUMMARY 


ALL 
SYSTEMS 

GRAND 
SUMMARY 


$ c. 

48,927.62 

123,548.71 


$ c. 
215.03 


$ c. 
382,856.81 
240,367.20 
443,500.81 


$ c. 
431,999.46 
363,915.91 

597,308.77 


$ c. 
10,186,471.28 
22,306,800.94 


140,613.54 


13,194.42 


21,152,681.20 
5,945,225.61 


62,413.22 
61,540.24 
29,781.46 


2,566.91 

2,344.61 

606 . 24 


67,012.85 
90,004.85 
77,096.02 


131,992.98 
153,889.70 
107,483.72 


9,478,605.14 
8,514,165.03 
2,381,599.40 
1,458,443.68 


6,038.64 


93.53 


32,543.86 
348,777.37 


38,676.03 
348,777.37 
293,762.46 


4,040,859.74 
502,978.62 


293,762.46 




5,016,755.92 








200,000.00 












766,625.89 

1,473.68 
6,000.00 


19,020.74 
2,691.86 


1,682,159.77 

70,484.76 

594,994.87 

88,750.99 

21,592.86 

240,087.76 

821,761.42 

1,088.37 


2,467,806.40 

74,650.30 

600,994.87 

118,463.61 

24,076.31 

417,992.81 

1,062,986.47 

1,088.37 


91,184,586.56 

1,696,489.24 
2,163,785.20 


28,951.61 
2,483.45 


761.01 


3,746,910.92 
1,226,043.30 


177,905.05 




9,386,176.58 


239,785.83 


1,439.22 


26,045,679.00 
253,581.84 








1,223,225.51 


23,912.83 


3,520,920.80 


4,768,059.14 


135,703,252.64 
75,416.85 












1,223,225.51 


23,912.83 


3,520,920.80 


4,768,059.14 


135,778,669.49 


415,500.00 
25,719.16 


6,876.12 
803.55 


361,165.28 
143,310.57 


783,541.40 
169,833 . 28 


42,606,145.29 

3,320,485.45 

206,398.00 


10,332.83 






10,332.83 


3,787,725.14 










451,551.99 


7,679.67 


504,475.85 


963,707.51 


49,920,753.88 


239,785.83 
69,227.30 
11,402.34 


1,439.22 
2,978.00 


821,761.42 

397,387.59 

76,441.73 


1,062,986.47 

469,592.89 

87,844.07 


26,045,679.00 

16,075,959.28 

2,048,081.84 








320,415.47 


4,417.22 


1,295,590.74 


1,620,423.43 


44,169,720.12 


252,150.00 
177,905.05 


3,123.88 


280,934.72 

240,087.76 

1,199,831.73 


536,208.60 

417,992.81 

1,229,726.79 


17,651,367.71 
9,386,176.58 


21,203.00 


8,692.06 


14,650,651.20 


451,258.05 


11,815.94 


1,720,854.21 


2,183,928.20 


41,688,195.49 


1,223,225.51 


23,912.83 


3,520,920.80 


4,768,059.14 


135,778,669.49 


34.0 


34.2 


18.7 


14.7 


39.5 



340 



TWENTY-SIXTH ANNUAL REPORT OF THE No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



NIAGARA 
SYSTEM 



Municipality 


Acton 
1,895 


Agincourt 
P.V. 


Ailsa 

Craig 

464 


Alvinston 
690 


Amherst- 


Population 


burg 
3,086 






Earnings 
Domestic service 


$ c. 

9,980.21 

3,956.25 

16,484.40 

663.43 

1,824.00 


$ c. 

5,107.67 
1,136.42 
1,289.18 


$ c. 

2,631.21 
1,469.89 
1,020.69 


$ c. 

3,991.86 

2,354.46 
174.71 
265.85 

1,854.00 


$ c. 
19,006.20 


Commercial light service 


6,657.90 


Commercial power service 


5,375.25 


Municipal power 






750.04 


620.50 


2,270.22 


Merchandise 




Miscellaneous 


329.11 


89.61 


302.49 


96.30 


675.97 






Total earnings 


33,237.40 


8,372.92 


6,044.78 


8,737.18 


33,985.54 






Expenses 
Power purchased 


26,866.21 


5,342.11 


4,525.23 


6,549.36 


21,591.10 


Substation operation 




Substation maintenance 












Distribution system, operation and 
maintenance 


2,361.66 
160.25 
217.85 


423.59 


254.61 


42.24 


2,350.28 


Line transformer maintenance 


20.64 


Meter maintenance 




169.51 




386.09 


Consumers' premises expenses 






34.04 


Street lighting, operation and main- 
tenance 


349.80 


145.87 


97.40 


85.37 


529.99 


Promotion of business 




Billing and collecting 

General office, salaries and expenses. . 

Undistributed expenses 

Truck operation and maintenance. . . 
Interest 


690.60 
444.97 
233.58 
140.29 
32.60 

649.58 

1,324.00 




181.24 

133.09 

34.79 


251.00 

215.88 

26.75 


2,303.87 


322.40 


981.51 
161.84 




286.08 


260.06 
566.40 
354.00 




742 . 73 

1,048.37 

597.00 


1,456.46 


Sinking fund and principal payments 
on debentures 




1,304.96 


Depreciation 


451.00 


1,846.00 














Total operating costs and fixed 
charges 


33,471.39 


7,414.43 


5,846.87 


9,558.70 


33,253.86 






Net surplus 




958.49 


197.91 




732.68 


Net loss 


233.99 


821.52 












Number of Consumers 

Domestic service 

Commercial light service 

Power service 


482 
89 
16 


143 

23 

3 


130 

38 

2 


151 

52 

2 


586 

124 

15 


Total 


587 


169 


170 


205 


725 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



341 



"B" 

Hydro Municipalities for Year Ended December 31, 1933 



Ancaster 
Twp. 


Arkona 
416 


Aylmer 
1,989 


Ayr 
768 


Baden 
P.V. 


Beachville 

P.V. 


Belle River 
746 


Blenheim 
1,690 


$ c. 

8,977.54 

1,788.77 

550.38 

292.14 


$ c. 

2,643.74 

1,649.92 

833 . 62 


$ c 

10,877.65 

6,877.10 

3,056.22 

901.31 

2,320.00 


$ c 

5,126.69 

1,852.48 

161.85 


$ c. 

3,596.36 
1,487.40 
4,821.19 


$ c. 

3,018.55 

662.16 

9,134.26 


.$ c 

3,411.84 

1,556.07 

432.15 

989.07 

693.00 


$ c 

8,520.56 
6,206.73 
3,506.91 
1,533.93 


1,135.00 


960 . 00 


1,028.00 


650.00 


517.00 


2,500.00 




38 


1,113.27 


15.35 


86.31 


303 . 60 


244.79 


162.66 






12,743.83 


6,087.66 


25,145.55 


8,184.37 


10,641.26 


13,635.57 


7,326.92 


22,430.79 


7,961.94 


4,013.87 


15,973.03 


5,664.40 


8,521.58 


14,486.13 


4,459.87 


13,304.73 


















1,136.55 
68.32 


131.54 


"2,584.85 

28.20 

211.86 


535.05 


260.99 


55.64 

38.54 

102.02 


457.55 
35.70 
34.80 


798.77 
135.09 


247.95 




17.64 




818.80 










161.70 


74 45 


275.28 


78.82 


174.44 


104.34 


122.20 


383.81 
18.44 




206.25 
88.70 


663 . 29 

1,218.10 

144.64 


430.86 
57.60 
27.00 


427.32 
54.61 
23.20 


271.71 

171.57 

25.68 


295.86 

317.06 

26.38 


934.41 


1,540.36 


1,127.42 
378.57 








544.61 
291.10 
844.00 


626.95 
563.21 
322.00 


1,228.83 
1,280.35 
1,408.00 


365.81 
349 . 60 
535.00 


115.60 
209.66 
370.00 


141.30 
223.30 
630.00 


350.65 
390.39 
635.00 


592.31 

476.84 

1,383.00 


















12,796.53 


6,026.97 


25,016.43 


8,061.78 


10,157.40 


16,250.23 


7,125.46 


20,352.19 




60.69 


129.12 


122.59 


483.86 




201.46 


2,078 60 


52.70 


2,614.66 


















268 
37 

5 


96 
36 


633 

133 

13 


208 
45 

3 


133 

35 

3 


133 

20 

4 


207 

46 

4 


490 

126 

10 








310 


132 


779 


256 


171 


157 


257 


626 



342 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Blyth 
602 


Bolton 
593 


Bothwell 
646 


Brampton 
5,413 


Brantford 


Population 


30,724 






Earnings 
Domestic service 


$ c. 

3,893.93 
1,821.29 
1,184.15 


$ c. 

3,426.17 

967 . 73 

2,327.48 


$ c. 

2,710.60 

1,259.10 

618.20 

145.94 

1,293.00 


$ c. 

36,818.92 

16,148.10 

15,162.91 

2,458.88 

5,426.50 


$ c 

184,129.33 

62,992.72 

163,495 28 


Commercial light service 

Commercial power service 


Municipal power 


21,488.11 


Street lighting 


1,300.00 


1,113.99 


34,414.16 


Merchandise 




Miscellaneous 


10.07 


9.70 


615.39 


1,329.01 


3,924.88 






Total earnings 


8,209.44 


7,845.07 


6,642.23 


77,344.32 


470,444.48 






Expenses 
Power purchased 


4,895.80 


5,020.91 


4,653.08 


63,640.64 
114.86 


317,694.31 


Substation operation 


7,722.48 


Substation maintenance 








574.83 


Distribution system, operation and 
maintenance 


154.62 


288.20 


104.55 


2,916.26 

95.95 

648.71 


14,197.85 


Line transformer maintenance 


219.06 


Meter maintenance 






99.95 


4,833.18 


Consumers' premises expenses 




65 
242 . 64 


414.50 


Street lighting, operation and main- 
tenance 


81.90 


189.10 


779.03 


4,528.75 


Promotion of business 


769.78 


Billing and collecting 






240 . 68 

252.10 

15.00 


1,614.35 
973.30 
775.93 
240.73 
731.77 

3,056.52 

4,267.00 

91.26 


9,293.44 


General office, salaries and expenses. . 
Undistributed expenses 


278.29 


419.50 


9,594.42 
3,935.12 


Truck operation and maintenance. . . 






2,363.12 


I nterest 


544.24 
986 87 
433 . 00 


332.87 
536.14 
544 . 00 


202.30 
170.30 
531.00 


27,940.74 


Sinking fund and principal payments 
on debentures 


50,548.93 


Depreciation . . . 


22,601.00 


Other reserves 


2,000.00 












Total operating costs and fixed 
charges 


7,374.67 


7,384.91 


6,458.06 


79,946.31 


479,231.51 


Net surplus 


834.77 


460.16 


184.17 






Net loss 


2,601.99 


8,787.03 












Number of Consumers 

Domestic service 

Commercial light service 


158 

55 
5 


162 

43 

9 


169 

48 

5 


1,369 
232 

54 


7,384 
1,124 


Power service . . 


229 






Total 


218 


214 


222 


1,655 


8,737 







1934 



HYDRO-ELECTRIC POWER COMMISSION 



343 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Brantford 
Twp. 


Bridgeport 
P.V. 


Brigden 
P.V. 


Brussels 
770 


Burford 
P.V. 


Burgess- 
ville 
P.V. 


Caledonia 
1,400 


Campbell- 
ville 
P.V. 


$ c 

18,445.68 
3,947.57 
3,972.99 


$ c 

3,714.20 

1,049.03 

259.09 


$ c 

2,306.85 
1,754.03 
1,026.74 


$ c 

5,318.84 

2,803.16 

749.06 


$ c 

4,240.32 

944 . 20 

1,532.87 


$ c 

1,254.32 
581.80 
286.05 


$ c 

5,314.46 
3,877.51 
2,303.00 


$ c 

1,317.96 
488.67 






4,250.50 


580.00 


745.00 


1,284.00 


737.04 


312.00 


1,546.98 


456.00 


705 . 23 




101.35 


94.27 


235.01 




102.76 


57.72 










31,321.97 


5,602.32 


5,933.97 


10,249.33 


7,689.44 


2,434.17 


13,144.71 


2,320.35 


17,753.55 


3,643.91 


4,236.29 


5,919.99 


4,794.58 


2,220.69 


8,346.97 


1,570.04 


















1,453.89 
125.31 


45.35 

20.17 

156.17 


. 472.47 


323.02 


96.29 


143.76 


1,391.15 
21.50 
79.46 


67.92 


366.43 


5.51 




81.19 














951.59 

105.55 


45.60 


63.85 


122.16 


62.03 


29.07 


280.15 


39.17 


1,924.54 


319.01 
71.22 
21.50 


221.57 

104.21 

25.00 




408 . 85 

125.41 

22.66 


112.13 

5.63 

17.25 


476.62 

210.57 

84.60 




1,625.98 
58.43 


640.34 


108.63 








1,581.82 
3,211.39 


611.05 


66.17 
270.19 
345.00 


782.14 
975.14 
563.00 


37.30 
363.91 
463.00 


62.72 
254.20 
200.00 

85.41 


121.25 
240.07 
770.00 


231.03 
257 20 


2,474.00 


499.00 


112.00 
















31,632.48 


5,432.98 


5,810.26 


9,325.79 


6,455.22 


3,130.86 


12,022.74 


2,385.99 




169.34 


123.71 


923.54 


1,234.22 




1,121.97 




310.51 


696 . 69 


65 64 
















751 

45 

5 


110 
19 

4 


108 
43 

5 


221 

66 

2 


191 

32 

4 


54 

21 

2 


326 

86 

8 


40 

8 






801 


133 


156 


289 


227 


77 


420 


48 



344 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality. . 
Population. . . . 



Cayuga 
705 



Chatham 
16,223 



Chippawa 
1,073 



Clifford 
454 



Clinton 
1,842 



Earnings 

Domestic service 

Commercial light service. . 
Commercial power service 

Municipal power 

Street lighting 

Merchandise 

Miscellaneous 



Total earnings. 



Expenses 

Power purchased 

Substation operation 

Substation maintenance 

Distribution system, operation and 
maintenance 

Line transformer maintenance 

Meter maintenance 

Consumers' premises expenses 

Street lighting, operation and main- 
tenance 

Promotion of business 

Billing and collecting 

General office, salaries and expenses. . 

Undistributed expenses 

Truck operation and maintenance. . . 

Interest 

Sinking fund and principal payments 
on debentures 



Depreciation . . 
Other reserves. 



Total operating costs and fixed 
charges 



Net surplus 
Net loss. . . 



Number of Consumers 



Domestic service 

Commercial light service. 
Power service 



Total 



3,271.60 
2,867.78 
1 ,404 . 86 



1,431.00 
12.92 



79,868.02 
67,913.97 
46,853.22 

4,799.33 

19,009.95 

329.77 

1,133.54 



* c 

6,135.21 

1,079.44 

318.50 

744.38 

1,096.00 



2,341.49 

1,581.17 

119.86 



862.17 



11,717.71 
5,931.47 
4,669.21 
1,128.13 
1,987.02 



12.15 



9.90 



75.22 



8,988.16 



219,907.80 



9,385.68 



4,914.59 



26,608.76 



5,298.58 



653 . 53 

1.30 

71.85 



119,898.76 
5,988.79 
2,324.89 

4,881.02 
1,416.01 
4,852.10 



5,133.34 



3,813.03 



16,906.79 
100.35 



1,068.72 



27.93 



13.50 



9.95 



602 . 1 1 

88.72 

139.83 



46.91 



559.34 

166.10 

60.17 



782.16 
880.27 
535.00 



3,536.35 

2,652.53 

10,330.56 

13,592.03 

3,752.63 

2,093.69 

14,583.71 

14,405.79 

15,250.29 

251.92 



326.21 

2.25 

441.73 

498 . 39 

96.69 



31.99 



71.08 



297.02 

84.57 
24.28 



463 . 25 
747.52 
889.00 



380.95 
169.49 
281.00 



885 . 28 

1,794.78 

418.72 

115.01 

2,437.40 

1,305.66 

1,860.00 



9,055.21 



219,811.07 



9,680.60 



5,120.21 



26,725.73 



96.73 



67.05 



294 . 92 



205.62 



116.97 



121 

54 

4 

179 



3,730 

716 

98 

4,544 



331 

31 

6 

368 



105 

40 

1 

146 



504 
129 

15 

648 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



345 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Comber 
P.V. 


Cottam 
P.V. 


Courtright 
348 


Dashwood 
P.V. 


Delaware 
P.V. 


Dorchester 
P.V. 


Drayton 
559 


Dresden 
1,488 


$ c 

2,354.18 
2,292.75 
3,049 S3 


$ c 

2,545.36 

1,298.35 

389.53 


$ c. 

1,604.43 

941.55 

98.47 

792.82 

774.00 


$ c. 

1,532.16 
879.68 
576.61 


$ c. 

1,331.90 
601.43 


$ c. 

2,483.10 
818.97 
269.73 


$ c. 

3,093.75 
1,887.84 
1,017.47 


$ c. 

6,212.10 
5,002.21 
4,462.18 






445 . 09 


512.00 


457.50 


451.00 


J264.00 


590.00 


750.00 


1,758.36 
150.42 


76.09 


84.24 


31.18 


112.02 


158.18 


118.77 


230.00 


200.62 


8,284.85 


4,774.98 


4,242.45 


3,551.47 


2,355.51 


4,280.57 


6,979.06 


18,230.98 


6,315.79 


2,582.55 


3,137.10 


2,543.64 


1,439.07 


3,257.94 


5,684.26 


12,059.91 


















99.98 


113.58 

98.55 

9.30 


. 15.54 


135.93 


27.10 


24.94 
79.35 
67.51 


202.16 


1,761.19 


20.35 




60 


8.11 




123.57 








68.88 


106.33 


57.75 


30.23 


25.72 


28.88 


110.98 


237.30 


262.24 

237.23 

37.98 


"427'24 


98.45 
66.09 
15.75 


133.40 

3.29 

20.75 


' 132'56 
12.50 


130.58 

7.54 
11.25 


"252^33 
28.09 


616.53 

558.01 
76.85 


119.65 
472.48 
434 . 00 


397.23 
355.91 
338.00 


248.36 
593.46 
215.00 


128.10 
111.56 
204 . 00 


115.83 
144.91 
145.00 


134.24 
148.31 
335.00 


403.00 

287.98 
516.00 


70.88 
691.43 
841.00 
225.00 


















8,068.58 


4,428.69 


4,447.50 


3,311.50 


2,050.80 


4,225.54 


7,484.80 


17,261.67 


216.27 


346.29 


205.05 


239.97 


304.71 


55.03 


505.74 


969.31 














98 
49 

3 


105 
28 

1 


58 
23 

2 


66 

27 
1 


48 
18 


124 

26 

1 


147 

58 

4 


372 

122 

10 








150 


134 


83 


94 


66 


151 


209 


504 



346 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Drumbo 
P.V. 


Dublin 
P.V. 


Dundas 
5,138 


Dunnville 
3,615 


Dutton 


Population 


761 


Earnings 
Domestic service 


$ c. 

2,130.97 

1,039.19 

753.76 


$ c. 

1,334.24 
887.79 
451.79 


$ c. 

20,753.93 

10,660.40 

16,577.44 

594.35 

5,388.00 


$ c. 

13,505.31 

11,480.33 

11,461.99 

2,378.46 

3,941.88 


$ c. 

3,545.07 
2,534.26 
3,552.14 


Commercial light service 


Commercial power service 


Municipal power 


Street lighting 


522.50 


750.00 


999 37 


Merchandise 




Miscellaneous 


77.89 




286.71 


222.89 


270.99 








Total earnings 


4,524.31 


3,423.82 


54,260.83 


42,990.86 


10,901.83 




Expenses 
Power purchased 


2,635.74 


2,232.76 


34,814.68 
86.94 


23,174.74 


7,784.84 


Substation operation 


Substation maintenance 










Distribution system, operation and 
maintenance 


208.09 


60.93 


5,250.20 

37.12 

828.99 


1,718.56 

20.93 

137.69 


362.81 


Line transformer maintenance 


183.13 


Meter maintenance 


107.72 




116.98 


Consumers' premises expenses 






Street lighting, operation and main- 
tenance 


65.01 


80.11 


461.63 


466.57 


223.64 


Promotion of business . 




Billing and collecting 


162.01 

101.63 

11.25 


150.06 
21.92 

15.75 


1,112.40 

1,682.98 

744.77 

683.22 

1,465.43 

2,082.65 

4,028.00 




331.72 


General office, salaries and expenses. . 

Undistributed expenses 

Truck operation and maintenance . . . 


2,479.32 
167.93 
177.65 

3,022.70 

2,487.10 
3,052.00 


138.65 
26.79 


Interest 


129.73 
163.00 
270.00 


148.19 
441.49 
271.00 


346.67 


Sinking fund and principal payments 
on debentures 


340.60 


Depreciation 


548.00 


Other reserves 
















Total operating costs and fixed 
charges 


3,854.18 


3,422.21 


53,279.01 


36,905 . 19 


10,403.83 






Net surplus 


670.13 


1.61 


981.82 


6,085.67 


498.00 


Net loss . 
















Number of Consumers 
Domestic service 


82 

25 

1 


40 

22 
3 


1,219 

193 

40 


766 

199 

34 


204 


Commercial light service 


71 


Power service 


7 






Total 


108 


65 


1,452 


999 


282 







1934 



HYDRO-ELECTRIC POWER COMMISSION 



347 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



East 

Windsor 

14.333 


East 
York Twp. 


Elmira 
2,642 


Elora 
1,144 


Embro 

455 


Erieau 
264 


Erie 
Beach 

23 


Essex 
1,888 


$ c. 

74,849.48 
16,038.88 
30,604 . 10 


$ c. 

175,276.26 

23,952.07 

22,408.69 

5,117.31 

19,637.45 


$ c. 

15,672.17 

5,681.70 

3,599.66 

827.29 

1,834.00 


$ c. 

7,125.01 
3,524.48 
2,907.45 


$ c. 

2,758.79 
1,586.05 
1,530.55 


$ c. 

3,652.19 

1,058.34 

879.43 


$ c. 

1,518.16 

258.57 


$ c. 

7,502.00 
4,666.24 

4,383.42 






1,669.44 


8,419.92 


1,674.00 

96.94 

397.09 


672.00 


360.00 




3,134.99 








142.38 


442.39 


61.67 






502.16 










129,912.38 


246,534.16 


28,057.21 


15,724.97 


6,609.06 


5,949.96 


1,776.73 


21,858.25 


73,289.08 


158,535.98 


20,696.12 


10,335.79 


4,285.42 


3,747.85 


877.83 


11,571.99 


















6,497.35 
317.06 


7,781.53 
2,102.43 
3,006.62 
1,147.19 

2,074.15 


1,768.00 


2,432.24 
17.56 
68.16 


79.77 

23.14 

4.68 


106.41 
55.35 
89.42 


175.27 


232.7a 
49.42 


2,799.55 
2,459.49 


124.63 


11.34 


64.66 


2,718.77 


105.99 


148.71 


204.55 


54.82 




282.06 


2,480.64 






10,294.90 
4,553.33 
3,029.19 
3,062.93 


10,636.12 
9,862.66 
3,817.34 
3,770.91 

15,151.56 

14,214.38 

12,772.00 

221.63 


635.45 
716.84 
412.43 
158.85 
1,457.16 

1,573.21 

1,978.00 


691.55 
454.05 
364.32 
105.04 
237.19 

732.10 

1,070.00 


343.12 

141.51 

17.59 


319.65 

118.19 

61.32 


160.38 
8.16 
7.50 


778.48 

1,927.41 

159.90 

213.97 


3,581.12 
6.708.47 
7,767.00 


228.61 
434.85 
477.00 


313.92 
324.96 
325.00 


161.51 

127.23 

76.00 


1,071.96 

476.71 

1,638.00 
















129,558.88 


245,094.50 


29,626.68 


16,656.71 


6,240.24 


5,516.89 


1,605.22 


18,467.34 


353.50 


1,439.66 






368.82 


433.07 


171.51 


3,390.91 




1,569.47 


931.74 
















2,971 
266 

33 


8,744 

367 

35 


505 
115 

22 


307 
73 

2 


99 

45 

1 


138 

12 

2 


63 

3 


413 
112 

17 








3,270 


9,146 


642 


382 


145 


152 


66 


542 



348 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



NIAGARA 

SYSTEM— Continued 



Municipality 
Population . . 



Etobicoke 
Twp. 



Exeter 
1,622 



Fergus 
2,559 



Fonthill 
862 



Forest 
1,465 



Earnings 

Domestic service 

Commercial light service. . 
Commercial power service. 

Municipal power 

Street lighting 

Merchandise 

Miscellaneous 



93,889.08 
16,220.69 
11,212.72 
4,478.63 
13,415.13 



* c. 

11,406.32 

4,896.67 

4,064.90 

542.21 

1,998.94 



15,720.00 
6,278.16 
7,615.45 

799.21 
2,915.04 

102.64 



4,877.99 
974.73 
238.17 
358.68 

1,065.00 



394.27 



570.76 



8.59 



* c. 

10,865.60 
5,208.04 
4,209.01 
1,062.18 
2,321.00 
49.28 
652.87 



Total earnings. 



139,610.52 



23,479.80 



33,430.50 



7,523.16 



24,367.98 



and 



Expenses 



Power purchased 

Substation operation 

Substation maintenance 

Distribution system, operation 
maintenance 

Line transformer maintenance 

Meter maintenance 

Consumers' premises expenses 

Street lighting, operation and main- 
tenance 

Promotion of business 

Billing and collecting 

General office, salaries and expenses. . 

Undistributed expenses 

Truck operation and maintenance. . . 

Interest 

Sinking fund and principal payments 
on debentures 



86,749.14 



15.467.63 



23,979.90 



3,816.05 



14,351.36 



8,161.68 

679.56 

1,199.31 



566.83 

34.20 

326.61 



Depreciation . . 
Other reserves. 



1,515.61 
1,045.34 
4,436.42 
2,655.76 
2,535.06 
1,645.09 
11,330.30 

11,534.81 

10,411.00 



264.73 
77.96 
423.42 
2,174.67 
109.12 
101.52 
458.58 

960.47 

1,334.00 



1,216.19 

72.50 

396.64 

12.00 

290.68 



570.53 



703.43 



102.81 



42.35 
30 



367.88 



630.82 
768.22 
207.43 
281.63 
1,135.77 

2,836.71 

1,510.00 



486.84 



1,019.53 

1,020.98 

472.00 



497.48 
2,214.48 
196.97 
284.37 
645 . 65 

1,056.82 

1,389.00 



Total operating costs and fixed 
charges 



143,899.08 



22,299.74 



33,338.49 



7,428.58 



21,810.25 



Net surplus. 
Net loss. . . 



180.06 



92.01 



94.58 



2,557.73 



4,288.56 



Number of Consumers 



Domestic service 

Commercial light service 
Power service 



Total 



3,114 
212 

22 

3,348 



452 

121 

9 

582 



618 

116 

13 

747 



194 
33 

5 

232 



458 

139 

24 

621 



934 



HYDRO-ELECTRIC POWER COMMISSION 



349 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Gait 
14,036 


George- 
town 
2,187 


Glencoe 
800 


Goderich 
4,366 


Granton 
P.V. 


Guelph 
20,754 


Hagers- 
ville 
1,370 


Hamilton 
154,701 


$ c. 

103,490.42 

41,981.08 

72,488.00 

4,441.00 


$ c. 

14,067.98 
6,022.90 

22,190.68 

506.49 

2,125.83 


$ c. 

5,470.81 
3,152.02 
1,541.71 
1,432.99 
1,934.00 


$ c. 

29,614.29 

13,509.59 

10,640.48 

3,429.33 

3,791.50 


$ c. 

1,692.71 

1,028.21 

830 . 74 


$ c. 

103,446.51 
49,053.55 
95,347.14 
11,864.16 
18,499.79 
755.77 
1,488.05 


$ c. 

4,816.57 

4,468.97 

11,477.85 


$ c. 

896,836.05 

346,737.41 

1,453,362.29 

54,487.69 


21,384.00 


370.00 


1,732.00 
39.69 

859.54 


123,449.34 


3,295.62 


737.63 


41.24 


187.81 


175.66 


22,459.92 


247,080.12 


45,651.51 


13,572.77 


61,173.00 


4,097.32 


280,454.97 


23,394.62 


2,897,332.70 


157,535.71 
4,287.58 


35,878.07 


9,215.72 


41,623.21 
1,750.09 


3,110.71 


210,624.16 
3,044.97 


19,561.72 


2,048,010.95 
61,889.21 


75.93 










8,450.50 


2,914.71 
67.52 


1,053.03 

37.09 

344.98 


582.40 


2,215.79 
171.64 
543.81 


121.42 


9,751.83 
705.37 

2,821.57 
210.69 

6,996.40 
219.75 
6,000.48 
8,653.05 
4,432.87 
1,323.37 
2,774.40 

5,656.52 

12,845.00 


2,655.22 

83.11 

183.71 


36,860.80 
9,473.80 


2,876.05 






17,589.68 








14,698.25 


3,153.09 
4,358.94 


274.80 


222.10 


623.28 


18.52 


128.14 


13,053.04 
17,737.88 


3,798.16 

3,797.30 

4,270.43 

733.80 


1,638.32 
782.25 
168.01 
543.13 
691.85 

765.41 

1,982.00 


532.69 
333.84 
46.49 
126.17 
539.24 

981.45 

906.00 


1,826.10 

2,134.74 

218.67 

203.68 

2,714.49 

2,231.60 

5,189.00 


159.75 
85.85 
15.98 


540.44 
660.12 
146.71 
544.40 
177.04 

373.76 

1,068.00 


50,189.04 
42,784.91 
43,371.88 


16,351.29 

18,563.27 

22,878.00 

3,000.00 


143.70 
119.18 
221.00 


250,855.06 
292,021.39 
127,175.00 


















248,661.78 


44,158.94 


13,486.10 


61,446.10 


3,996.11 


276,060.43 


26,122.37 


3,034,161.39 




1,492.57 


86.67 




101.21 


4,394.54 






1,581.66 


273.10 


2,727.75 


136,828.69 














3,584 
484 
118 


668 
132 

27 


218 

80 

6 


1,155 

237 

20 


80 
33 

2 


5,008 
760 
130 


316 

107 

17 


36,990 
5,068 
1,265 


4,186 


827 


304 


1,412 


115 


5,898 


400 


43,323 



350 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Harriston 
1,293 


Harrow 
926 


Hensall 
719 


Hespeler 

2,784 


Highgate 
338 


Population 






Earnings 


$ c. 

7,829.33 
4,842.28 
5,091.22 
477.06 
1,467.00 


$ c. 

7,875.06 
3,499.99 

3,558.36 

1,249.44 


$ c. 

4,180.44 

1,800.34 

2,518.55 

37.56 

996.00 


$ c. 

18,265.53 
4,916.32 

35,121.46 
1,103.95 
2,965.00 


$ c. 

1,783.58 
976 17 


Commercial light service 


Commercial power service 


1,081.68 
39 01 




Street light 


568.00 


Merchandise 




Miscellaneous 




50.19 


244.24 


496.57 


170.08 








Total earnings 


19,706.89 


16,233.04 


9,777.13 


62,868.83 


4,618.52 




Expenses 
Power purchased 


13,089.24 


12,347.82 


6,992.59 


49,949.40 

310.84 

11.00 

2,384.26 

42.72 

169.36 


2,972.71 






Substation maintenance 










Distribution system, operation and 
maintenance 


1,182.25 


150.05 
16.94 

125.71 


332.27 


37.77 


Line transformer maintenance 




Meter maintenance 


145.25 




9 40 


Consumers' premises expenses 






Street lighting, operation and main- 
tenance 

Promotion of business 


267.68 


273.32 

53.88 

632.60 

437.12 

28.25 


114.10 


602.72 


97.52 


Billing and collecting 


825.74 
118.11 
93.03 
165.77 
577.59 

721.66 

953.00 


348.50 

415.07 

29.35 


661.59 

1,257.96 

482.34 

289.16 

2,000.75 

2,735.69 

2,492.00 


348.63 


General office, salaries and expenses. . 

Undistributed expenses 

Truck operation and maintenance . . . 

Interest 

Sinking fund and principal payments 
on debentures 

Depreciation 


133.12 

15.75 


526.23 
519.93 
682 00 


438.95 
423.48 
625.00 


177.84 
165.85 
333.00 


Other reserves 
















Total operating costs and fixed 
charges 


18,139.32 


15,793.85 


9,719.31 


63,389.79 


4,291.59 


Net surplus 

Net loss 


1,567.57 


439.19 


57.82 




326.93 


520.96 














Number of Consumers 

Domestic service 

Commercial light service 

Power service 


338 

105 

12 


246 

77 
4 


180 
52 
14 


700 

108 

28 


96 

37 

6 


Total 


455 


327 


246 


836 


139 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



351 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



H umber- 
stone 
2,265 


Ingersoll 
5,296 


Jarvis 
504 


Kingsville 
2,286 


Kitchener 
31,443 


Lambeth 
P.V. 


La Salle 
600 


Leaming- 
ton 
5,025 


$ c. 

8,447.65 
2,998.76 
3,912.05 


$ c. 

31,581.32 

14,380.17 

23,673.54 

2,039.45 

4,851.48 

10.98 

542.47 


$ c. 

2,396.78 
1,868.82 
4,220.35 

' 840'00 


$ c. 

14,073.03 
6,544.89 
3,366.09 
1,207.24 
3,220.00 


$ c. 

193,447.44 
98,357.80 

197,453.09 
20,660.15 
32,415.74 


$ c. 

3,387.28 
1,511.67 

576.57 

459.00 


$ c. 

6,313.91 
1,666.45 

2,254.05 


$ c. 

25,306.03 

13,751.06 

10,924.25 

5,324.06 


1,367.00 


577.50 


5,456.34 


464 . 80 


97.18 


1,124.79 


864.43 


56.28 


143.22 


875.61 


17,190.26 


77,079.41 


9,423.13 


29,536.04 


543,198.65 


5,990.80 


10,955.13 


61,637.35 


9,429.08 


60,705.42 
717.50 


6,751.50 


16,082.70 


403,835.00 

8,771.81 

797.95 

14,680.84 

161.81 

4,404.47 

1,378.55 

6,701.85 

663.38 

13,044.80 

13,430.50 

5,575.44 

3,851.29 

11,657.75 

24,044.92 

28,993.00 

2,564.88 


4,033.14 


6,926.92 


37,851.83 














814.30 
2.40 


2,674.64 
562.49 
148.22 
189.53 

510.23 

58.10 

1,386.15 

4,635.02 

442.72 

411.07 

3,387.13 

1,677.35 

3,335.00 


171.40 
" 20 '. 50 


1,008.75 

99.92 

249.01 


51.32 

3.82 

127.38 


426.32 


2,637.19 
47.21 


26.80 




603 . 14 






62.43 


122.38 


45.10 


658.69 


47.50 


90.00 


939.31 




505.95 
36.73 

23.72 


1,335.45 

1,032.46 

380.50 

191.77 

1,758.32 

675.37 

1,883.00 


"217.33 
15.00 

155.74 

136.24 
326.00 


571.10 
503.40 
74.52 
321.89 
722.91 

633.57 

795.00 


2,306.04 

2,965.10 

719 13 


839.28 


113.43 


500.34 


1,230.95 
1,200.00 
1,040.00 


391.07 
487.57 
386.00 


2,105.11 
2,079.75 
3,218.00 
















14,818.62 


80,840.57 


8,819.54 


25,355.94 


544,558.24 


5,113.47 


11,065.63 


56,034.58 


2,371.64 




603.59 


4,180.10 




877.33 




5,602.77 




3,761.16 


1,359.59 


110 50 












500 
64 

7 


1,265 

234 

44 


120 

36 

4 


706 

174 

14 


7,117 
956 
239 


109 

28 
2 


198 
21 

5 


1,324 

255 

26 


571 


1,543 


160 


894 


8,312 


139 


224 


1,605 



352 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 

Population 


Listowel 
2,665 


London 

73,173 


London 
Twp. 


Long 

Branch 

3,541 


Lucan 
590 


Earnings 
Domestic service 


$ c. 

17,760.49 
7,947.24 

11,468.64 
1,504.67 
3,839.10 


$ c. 

492,592.98 

188,474.27 

316,997.15 

49,029.36 

54,028.74 

2,894.60 

31,413.71 


$ c. 

10,610.79 
2,446.39 
1,537.05 


$ c. 

23,463.32 

5,270.04 

779.45 

994.12 

3,413.27 


$ c. 
4,777 67 


Commercial light service 

Commercial power service 

Municipal power 

Street lighting 

Merchandise 


1,617.17 
370.86 


832.50 


992.70 


Miscellaneous 


642.62 


413.43 


108.00 


316 54 






Total earnings 


43,162.76 


1,135,430.81 


15,840.16 


34 ; 028.20 


8,074.94 


Expenses 

Power purchased 

Substation operation 

Substation maintenance 


31,664.62 
59.72 


762,305.39 
16,101.15 
11,647.78 

19,767.37 
3,134.48 

13,465.77 
4,466.07 

10,172.51 
5,969.48 
26,778.58 
33,679.83 
10,257.36 
6,431.59 
48,462.11 

63,052.93 

91,824.95 

12,166.28 


11,062.35 


20,475.98 


4,911.08 








Distribution system, operation and 

maintenance 

Line transformer maintenance 


2,560.37 
244.27 
556.56 


287.19 


3,418.08 

56.99 

229.85 


609.43 


Meter maintenance 


246.96 




Consumers' premises expenses 




Street lighting, operation and main- 
tenance 


405.96 
11.54 
812.58 
617.08 
321.31 
173.88 
549.34 

1,722.10 

2,525.00 


161.49 

7.11 

600.28 

665 . 10 

22.38 


536.33 

11.25 

2,093.32 

1,934.47 

869.09 


130.15 


Promotion of business 




Billing and collecting 


504.63 


General office, salaries and expenses. . 

Undistributed expenses 

Truck operation and maintenance. . . 

Interest 

Sinking fund and principal payments 
on debentures 


400.37 
40.76 


672.27 
965.35 
690.00 


1,988.88 
1,899.79 
2,166.00 


229.14 

258.75 


Depreciation 


625.00 


Other reserves 














Total operating costs and fixed 
fixed charges 


42,224.33 


1,139,683.63 


15,380.48 


35,680.03 


7,709.31 






Net surplus 


938.43 




459.68 




365.63 


Net loss 


4,252.82 


1,651.83 












Number of Consumers 
Domestic service 


726 
152 

21 


16,367 

2,839 

486 


330 
19 

5 


899 

68 

3 


174 


Commercial light service 

Power service 


44 

7 






Total 


899 


19,692 


354 


970 


225 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



353 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Lynden 
P.V. 


Markham 
1,073 


Merlin 
P.V. 


Merritton 
2,544 


Milton 
1,828 


Milverton 
1,004 


Mimico 
6,454 


Mitchell 
1,571 


$ c. 

2,151.80 
713.59 
749.82 


$ c. 

6,880.40 
2,614.73 
2,772.35 
490 . 25 
1,356.00 


$ c. 

2,261.27 
1,704.94 
1,470.08 


$ c. 

11,558.62 

2,241.79 

59,639.69 


$ c. 

11,622.25 

5,463.21 

11,308.00 


$ c. 

5,672.73 

2,775.02 

3,544.03 

549.60 

999.00 


$ c. 

54,604.89 
9,519.99 
3,477.41 
7,700.76 
8,021.89 


$ c. 

10,478.52 

4,196.91 

4,080.52 

830 22 


431.80 


688.00 


3,352.00 


2,019.50 


2,088.00 
927.11 


7.53 


160.67 


326.39 


267.85 


1,740.01 


87.10 


121.05 


190.59 


4,054.54 


14,274.40 


6,450.68 


77,059.95 


32,152.97 


13,627.48 


83,445.99 


22,791.87 


3,247.16 


9,272.27 


3,979.24 


64,931.76 


20,567.45 
244.13 


10,295.00 


53,807.49 


14,560.37 
102 77 
















64.20 


947.59 


89.98 


3,073.20 


1,660.68 


329.65 


7,089.10 

71.31 

950.83 

13.00 

1,166.74 


670.34 


11.59 




74.49 


390.07 


346.18 


187.22 
3.57 

85.37 


220 80 




2.59 
194.47 




43.17 


57.50 


864.00 


218.87 
166.00 
935.85 

2,107.06 
200.38 
355.63 

1,532.64 

2,218.30 


408.91 


160.49 




298.80 

301.84 

15.00 

"505.95 

671.76 

355.00 


1,029.67 

1,845.88 

193.05 

339.22 

1,194.75 

1,503.67 

1,996.00 


537.65 
313.93 
191.66 

172 .72 

677.11 
676.00 
675.00 


1,637.61 

2,155.82 

313.27 

626.50 

5,000.91 

5,353.04 

5,235.00 


1,040.94 

1,463.54 

661 46 


60.61 
20.00 


778.52 




169.85 
92.36 

371.51 

779.00 


118 90 


155.08 
154.20 


2.25 


266.00 


2,899.00 
















4,182.50 


12,608.16 


6,349.56 


77,361.27 


30,553.17 


14,144.88 


83,420.62 


22,149.28 




1,666.24 


101.12 




1,599.80 




25.37 


642 59 


127.96 


301.32 


517.40 
















81 
21 

1 


272 
66 
11 


104 
45 

2 


700 
60 
11 


456 

104 

21 


223 

71 

7 


1,760 

138 

15 


429 
99 
24 


103 


349 


151 


771 


581 


301 


1,913 


552 



354 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



NIAGARA 

SYSTEM— Continued 



Municipality 
Population. . 



Moore- 
field 
P.V. 



Mount 

Brydges 

P.V. 



Newbury 
267 



New 

Hamburg 
1,426 



New 

Toronto 
7,280 



Earnings 

Domestic service 

Commercial light service. . 
Commercial power service. 

Municipal power 

Street lighting 

Merchandise 

Miscellaneous 



1,068.82 

647.64 

1,161.94 



2.832.07 
915.76 
917.24 



1,266.73 
957.67 
760.22 



10,770.96 
4,255.63 
4,594.44 



375.00 
54.73 



500.00 



211.45 



720.00 
24.86 



2,258.75 
229.14 
173.23 



32,307.33 
12,113.15 
95,773.91 
10,926.65 
8,913.96 



Total earnings 



3,308.13 



5,376.52 



3,729.48 



22,282.15 



160,035.00 



and 



Expenses 

Power purchased 

Substation operation 

Substation maintenance 

Distribution system, operation 
maintenance 

Line transformer maintenance 

Meter maintenance 

Consumers' premises expenses 

Street lighting, operation and main- 
tenance 

Promotion of business 

Billing and collecting 

General office, salaries and expenses. . 

Undistributed expenses 

Truck operation and maintenance . . . 

Interest 

Sinking fund and principal payments 
on debentures 



2,699.72 



3,548.38 



2,254.82 



15,516.92 
369.04 



135,895.07 



21.60 



176.30 
55 '93 



98.95 



319.24 



497.92 



25.31 



43.75 



48.70 



118.82 



173.57 

106.30 

21.73 



124.83 
15.75 



Depreciation . . 
Other reserves 



94.38 
290.65 
185.00 



137.64 
152.72 
290.00 



295.96 
500.00 
287.00 



353.29 
29.09 
562.06 
839.54 
116.20 
232.15 
385.97 

792.52 

1,300.00 



4,627.57 
337.04 
636.05 
247.38 

1,777.42 

2,703.22 
4,806.67 
1,468.24 
1,157.29 
827.68 

304.25 

5,205.00 



Total operating costs and fixed 
charges 



3,435.48 



4,706.32 



3,626.01 



21,313.94 



159,992.88 



Net surplus 
Net loss . . . 



670.20 



103.47 



968.21 



42.12 



127.35 



Number of Consumers 



Domestic service 

Commercial light service. 
Power service. „ 



Total. 



136 

36 

3 

175 



343 
93 
14 

450 



1,434 

151 

34 

1,619 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



355 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Niagara 
Falls 
18,507 


Niagara-on- 

the-Lake 

1,672 


North York 
Twp. 


Norwich 
1,126 


Oil 

Springs 

433 


Otterville 
P.V. 


Palmerston 
1,617 


Paris 
4,330 


$ c. 

138,423.29 
55,590.67 
49,627.60 
15,238.33 
28,392.66 


$ c. 

14,217.28 

3,410.85 

852.84 

1,621.21 

2,833.31 

277.05 

322.31 


$ c. 

94,813.34 

15,325.38 

27,640.58 

3,927.85 

3,675.61 


$ C 

8,128.33 
3,068.33 
1,595.16 

634.90 

2,120.00 

94.35 

192.95 


$ c. 

1,636.56 
1,168.42 
7,848.65 


$ c. 

2,115.40 

1,656.94 

160 65 

108.10 

780.51 


$ c. 

10,859.15 
4,888.74 
4,666.92 
1,900.85 
1,738.98 


$ c. 

22,861.22 
8,245.31 

12,373.70 
1,225 00 


750.00 


5,838.90 


59.69 


480.97 


222.67 


124.91 


6.32 


1,798.24 


287,332.24 


23,534.85 


145,863.73 


15,834.02 


11,626.30 


4,946.51 


24,060.96 


52,342.37 


181,553.04 
10,386.43 


13,429.40 


81,895.54 


11,067.84 


7,107.19 


3,596.84 


17,853.90 


33,767.22 
170.46 


















8,858.38 
168.28 


2,362.97 


10,471.07 

369.63 

1,363.61 


1,467.21 


535.44 


43.30 
16.04 
74.92 


649.80 

29.15 

189.60 


4,756.19 
114.61 


5,442.10 


69.68 


59.66 


25.67 


422.15 
96.36 


3,355.89 


485.67 


674.97 


263.59 


39.47 


70.56 


355.74 


660.87 


7,215.69 




4,434.66 
3,648.88 
2,610.56 
3,298.98 
20,862.62 

15,944.89 

11,206.00 


412.61 
309.13 
178.85 
176.20 
332.92 

565.34 

822.00 


373.63 

349.42 

82.73 


252.77 
75.94 
19.50 


656.76 
764.26 
99.37 
115.45 
366.42 

863.87 

1,213.00 


1,245.42 


8,844.93 
4,940.08 


1,950.20 


1,249.33 
303.78 


3,348.62 


331.58 
1,220.07 

949 . 10 

1,519.00 


352.11 


20,800.73 
24,472.06 
23,016.00 


364.39 

1,128.19 

691.00 


73.13 
329.40 
410 00 


564.23 

696.52 

4,915.00 

186.89 


















302,402.23 


22,317.67 


156,781.41 


15,655.35 


10,697.13 


4,962.40 


23,157.32 


49,501.14 




1,217.18 




178.67 


929.17 




903.64 


2,841.23 


15,069.99 


10,917.68 


15.89 














4,329 

669 

87 


464 
82 
10 


2,802 

233 

36 


359 

77 
7 


75 
30 
31 


102 

43 

4 


389 
90 
11 


1,060 
180 

27 


5,085 


556 


3,071 


443 


136 


149 


490 


1,267 



356 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Parkhill 
998 


Petrolia 
2,569 


Plattsville 
P.V. 


Point 

Edward 

1,211 


Port 


Population 


Colborne 
6,006 




Earnings 
Domestic service 


$ c. 

4,742.41 

3,052.58 

287.57 

538.80 

1,437.00 


$ c. 

11,576.04 

6,517.41 

21,684.65 


$ c. 

2,610.72 

1,055.17 

532.83 


$ c. 

5,693.23 

2,009.55 

17,972.48 


$ c. 

27,055.82 

11,314.48 

6,914.32 

6,419.45 

7,825.80 


Commercial light service 


Commercial, power service 


Municipal power 


Street lighting 


2,652.00 
238.00 
474.65 


442.00 


1,553.66 


Merchandise 


Aliscellaneous 


11.25 


13.18 


625.73 








Total earnings 


10,069.61 


43,142.75 


4,653.90 


27,854.65 


59,529.87 




Expenses 

Power purchased 

Substation operation 


7,747.92 


27,646.63 


3,065.25 


22,880.12 


35,390.98 


Substation maintenance 












Distribution system, operation and 


261.19 


2,497.23 
667.76 
298.02 


62.40 


397.55 

15.15 

164.10 


1 838 03 


Line transformer maintenance 


337 74 


Meter maintenance 


170.70 


898 . 09 


Consumers' premises expenses 


81.56 


Street lighting, operation and main- 


222.30 


371.74 




225.64 


1,934.93 


Promotion of business 




726.10 


Billing and collecting 

General office, salaries and expenses. . 

Undistributed expenses 

Truck operation and maintenance. . . 


251.15 

108.20 

24.74 


457.21 

2,032.92 

246.29 

201.03 

1,479.45 

2,236.50 

2,807.00 

400.00 


166.85 

7.86 

15.75 


"l, 848. 80 
80.51 


1,614.19 

3,357.49 

287.30 

1,071.08 




418.56 
982.52 
691.00 


151.00 
189.67 
254.00 


536.43 

945 . 69 

1,045.00 


4,328.06 


Sinking fund and principal payments 


6,754.90 


Depreciation 


4,242.00 


Other reserves 














Total operating costs and fixed 
charges 


10,878.28 


41,341.78 


3,912.78 


28,138.99 


62,862.45 






Net surplus 




1,800.97 


741.12 






Net loss 


808.67 


284.34 


3,332.58 










Number of Consumers 
Domestic service 


238 

79 

4 


667 
167 

55 


91 
26 

1 


300 

44 

9 


1,249 


Commercial light service 


224 




25 






Total 


321 


889 


118 


353 


1,498 







1934 



HYDRO-ELECTRIC POWER COMMISSION 



357 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Port 
Credit 
1,650 


Port 

Dalhousie 

1,331 


Port 
Dover 
1,680 


Port 

Rowan 

674 


Port 
Stanley 

723 


Preston 
6,138 


Princeton 
P.V. 


Queenston 
P.V. 


$ c. 

13,127.25 

4,609.43 

892.93 

1,311 .91 


$ c. 

13,147.96 
2,736.23 
5,038.13 


$ c. 

8,036.80 
4,405.46 
4,976.57 


$ c. 

3,479.35 

1,657.90 

90.49 


$ c. 

12,781.37 

3,704.61 

3,470.65 

727.80 

2,003.16 


$ c. 

40,489.55 

15,920.17 

32,698.58 

954.78 

4,986.96 


$ c. 

2,143.41 

697.24 

3,075.76 


$ c. 

2,539.83 
818.72 
187.73 


2,710.00 


1,630.00 


2,964.17 


1,242.00 


481.00 


456.10 


39.50 


143.34 






307.70 


965.27 


15.83 


32.00 










22,691.02 


22,695.66 


20,383.00 


6,469.74 


22,995.29 


96,015.31 


6,413.24 


4,034.38 


18,405.63 


15,064.63 


11,301.52 


3,799.50 


13,687.99 


65,046.64 

4,301.33 

22.96 

2,559.87 

438.79 

1,256.03 

98.73 

884.59 

52.16 

1,693.98 

1,499.78 

815.07 

650.66 

2,831.28 

5,185.56 

8,095.00 

100.00 


5,082.38 


2,318.16 
















837.14 
39.24 


1,652.03 
439.26 


936.71 

56.86 

151.60 


246.25 


2,080.79 

2.60 

133.50 


60.82 


199.22 


52.35 


55.78 






21.95 






326.73 


261.00 


346.75 


48.61 


173.62 


75.58 


67.54 


1,192.01 

411.33 

53.19 


657.00 
786.86 
70.44 
336.80 
663.30 

1,277.85 

947.00 


454 . 66 

292.58 

30.98 


204.00 

188.66 

23.41 


617.47 
598.46 
115.19 
205.65 
411.44 

821.38 

1,231.00 


160.75 
34.75 
22.50 


"324.05 


416.49 

535.09 

1,466.00 


800 . 23 
2,094.47 
1,260.00 


1,009.32 
400.17 
338.00 


104.06 

128.58 
244.00 


346.57 
465.37 
318.00 
















23,757.15 


22,156.17 


17,726.36 


6,313.70 


20,079.09 


95,532.43 


5,913.42 


4,038.91 




539.49 


2,656.64 


156.04 


2,916.20 


482.88 


499 . 82 




1,066.13 


4.53 


















400 

72 
6 


587 
55 
10 


476 

122 

12 


101 

30 

1 


596 
97 
10 


1,552 
237 

57 


77 

20 

3 


68 
11 

1 


478 


652 


610 


132 


703 


1,846 


100 


80 



338 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Richmond 
Hill 
1,270 


Ridgetown 
1,942 


Riverside 
5,125 


Rockwood 
P.V. 


Rodney 

757 


Population 






Earnings 
Domestic service 


$ c. 

7,421.53 
3,736.73 
2,507.11 

472.46 

1,389.00 

52.93 

1 16 . 28 


$ c. 

9,111.63 

4,836.72 

3,477.74 

827.82 

3,115.00 

141.12 

637.53 


$ c. 

38,813.62 
4,275.26 
7,569.56 
2,087.37 
2,919.72 


$ c. 

2,976.57 
948.07 
257.99 


$ c. 
3,349.64 


Commercial light service 

Commercial power service 


2,393.00 
2,172.43 


Municipal power 

Street lighting 




765.00 


1,032.02 


Merchandise 




Miscellaneous 


255.37 


53.83 


150.00 


Total earnings 


15,696.04 


22,147.56 


55,920.90 


5,001.46 


9,097 09 






Expenses 
Power purchased 


9,004.24 


16,469.32 


38,002.59 


3,814.30 


6,127.85 


Substation operation 




Substation maintenance 












Distribution system, operation and 
maintenance 


1,258.92 


1,108.70 

246 . 14 

522.16 

62.09 

459.66 


859.37 

89.42 

1,012.70 

943.00 

835.60 
865.47 
3,635 . 25 
1,783.18 
1,133.43 
943 . 13 
3,491.29 

3,761.13 

3,871.00 


145.33 


404.14 


Line transformer maintenance 




Meter maintenance 




45.78 


148.72 


Consumers' premises expenses 






Street lighting, operation and main- 
tenance 


229.97 


64.50 


184.30 


Promotion of business . . 




Billing and collecting 




1,024.60 

940.62 

74.10 

167.18 

415.26 

357.66 

1,300.00 




347.50 


General office, salaries and expenses. . 
Undistributed expenses 


600.21 


444 . 78 
22.92 


245.57 
29.51 


Truck operation and maintenance. . . 






Interest 


257.60 
677.16 
533.00 


121.22 

79.39 

427.00 


314.96 


Sinking fund and principal payments 
on debentures 


276.37 


Depreciation 


425.00 


Other reserves 
















Total operating costs and fixed 
charges 


12,561.10 


23,147.49 


61,226.56 


5,165.22 


8,503.92 






Net surplus . . 


3,134.94 








593.17 


Net loss 


999.93 


5,305.66 


163.76 










Number of Consumers 
Domestic service 


321 
60 
17 


557 
144 

24 


1,081 

47 

8 


145 

34 

2 


202 


Commercial light service. '. 


73 


Power service 


7 






Total 


398 


725 


1 136 


181 


282 







1934 



HYDRO-ELECTRIC POWER COMMISSION 



359 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



St. Catharines 
26,192 


St. Clair 
Beach 


St. George 
P.V. 


St. Jacobs 
P.V. 


St. Marys 
4,016 


St. Thomas 
16,275 


Sandwich 
11,017 


$ c. 

144,062.04 
47,684.43 
86,508.23 


$ c 

2,297.25 

1,133.89 

374.68 


$ c 

2,876.52 
1,026.14 
2,168.29 


$ c. 

3,829.52 
1,134.57 
1,030.20 


$ c 

28,360.01 

9,291.65 

14,183.81 

2,674.49 

4,096.75 

189.10 

187.53 


$ c 

107,077.52 

46,670. W 

42,915.85 

5,617.68 

14,604.46 


$ c. 

88,361.44 
16,649 87 
12,067.13 


20,524.24 




370.50 


460.00 


9,874.46 






140.31 


4,262.84 




110.99 


160.58 


2,789.64 


562.62 








303,041.78 


3,805.86 


6,552.44 


6,614.87 


58,983.34 


219,675.44 


127,655.83 


190,682.11 
4,174.09 


2,786.45 


5,749.34 


5,359.74 


46,680.61 

1,150.76 

95.82 

2,551.90 

424.48 

745.87 

34.35 

1,315.80 


158,232.48 
6,982.45 
1,549.23 

9,668.72 

889 . 16 

2,137.46 

1,799.33 

3,004.44 
52.74 
4.783.04 
11,000.52 
4,119.52 
1,419.87 
1,475.83 

4,839.07 

12,610.00 


91,437.13 










24.40 


12,430.10 
1,228.63 


136.34 
22.93 
55.97 

27.55 


57.13 


53.48 


1,639.56 
416.55 


5,555.09 


231.73 




1,815.72 


2,266.58 




318.21 


3,251.98 


68.15 


31.65 
3.00 


1,752.01 


38.00 


29.57 
185.75 
31.59 
97.92 
63.28 
261.71 

333.73 

317.00 




9,760.82 


545.96 
51.51 
24.20 


1,283.72 

1,208.30 

622.91 

514.84 

2,322.37 

2,163.58 

4,388.00 

90.15 


5,511.82 


10,761.91 
4,436.52 


430.40 


5,865.36 
1,270.33 


2,101.48 




1,098.92 


11,977.28 
12,950.11 
16,868.00 


196.81 
216.02 
300.00 


117.90 
384.19 
349.00 


6,210.56 
6,450.31 
5,735.00 














288,482.70 


4,349.79 


7,440.85 


6,729.36 


65,593.46 


224,563.86 


129,545 88 


14,559.08 
















543.93 


888.41 


114.49 


6,610.12 


4,888.42 


1,890.05 




6,361 
710 
152 


38 
8 

2 


132 
36 

3 


109 

28 
6 


1,034 

195 

37 


3,999 

635 

80 


2,392 

210 

29 


7,223 


48 


171 


143 


1,266 


4,714 


2,631 



360 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 





Sarnia 
17,801 


Scarboro' 
Twp. 


Seaforth 
1,692 


Simcoe 
5,397 


Springfield 
379 


Population 






Earnings 
Domestic service 


$ c. 

104.443.09 

45,760.80 

167,781.48 


$ c. 

88,543.29 
17,694.05 
9,958.30 
11,227.44 
14,911.65 


$ c. 

10,808.12 

5,076.86 

4,162.74 

656.01 

1,788.00 

398.56 

608.31 


$ c. 

20,283.75 

24,148.61 

23,340.23 

2,388.41 

4,527.48 


$ c. 

1,656.59 
707 14 


Commercial light service 




1,060.65 


Municipal power 


Street lighting 


18,456.98 


550 00 


Merchandise 




Miscellaneous 


4,016.71 


436.55 


717 58 


251 83 






Total earnings 


340,459.06 


142,771.28 


23,498.60 


75,406.06 


4,226.21 




Expenses 


237,328.45 
8,228.99 

354.75 

6,876.14 

769.34 

3,333.21 


82,430.26 


16,215.02 


44,150.24 
467 . 24 


3,662.78 




Substation maintenance 


123.27 

5,822.56 

1,093.99 

1,106.31 

296.62 

1,723.58 


7.95 
1,578.14 
" 126.77 




Distribution system, operation and 
maintenance 


3,740.82 

89.99 

1,422.07 

135.94 

853.99 
71.64 

1,523.73 

2,185.73 

649 . 24 

587.52 

2,711.63 

2,948.96 

3,360.00 


10.48 


Line transformer maintenance 




Meter maintenance 


100.40 


Consumers' premises expenses 




Street lighting, operation and main- 
tenance 


6,041.61 
1,842.59 
6,689.54 
10,747.76 
5,858.44 
2,816.90 
8,864.06 

20,422.66 

17,715.00 


330.00 


67.08 


Promotion of business 




Billing and collecting 


5,586.84 
6,335.47 
2,811.20 
1,841.98 
11,728.27 

13,386.95 

10,650.00 

130.00 


830.36 
369.55 
108.89 
192.35 
1,251.60 

445 . 75 

1,752.00 


300.19 


General office, salaries and expenses. . 
Undistributed expenses 


71.37 
21.25 


Truck operation and maintenance. . . 
Interest 




211.16 


Sinking fund and principal payments 
on debentures . . 


168.66 


Depreciation . . 


337.00 


Other reserves 














Total operating costs and fixed 
charges 


337,889.44 


145,067.30 


23,208.38 


64,898.74 


4,950.37 






Net surplus 


2,569.62 




290.22 


10,507.32 




Net loss 


2,296.02 


724.16 












Number of Consumers 
Domestic service 


4,546 
610 

85 


4,404 

361 

30 


391 
105 

15 


1,144 
306 

38 


98 


Commercial light service 


30 


Power service 


3 






Total 


5,241 


4,795 


511 


1,488 


131 







1934 



HYDRO-ELECTRIC POWER COMMISSION 



36 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Stamford 
Twp. 


Stouffville 
1,105 


Stratford 
18,869 


Strathroy 
2,879 


Sutton 
809 


Tavistock 
1,042 


Tecum seh 
2,546 


Thames- 
ford 
P.V. 


$ c. 

51,719.41 
6,593.80 
3,852.98 
1,826.90 


$ c. 

7,124.57 

2,739.57 

839.91 


$ c. 

146,586.63 
51,772.30 
51,420.95 
12,209.44 
16,539.00 


$ c. 

20,207.78 
9,754.05 
9,319.2(9 
1,501.00 
4,075.71 


$ c. 

7,578.25 
2,981.82 
1,073.01 


$ c. 

6,906.75 
2,051.73 
8,476.95 
460.57 
1,212.00 


$ c. 

14,603.68 
3,171.42 
1,322.34 


$ c. 

2,428.13 
1,310.32 
2,979.91 


7,914.64 


1,764.00 


1,861.00 


960.00 


517.00 




324.25 


6,495.66 


1,015.18 


152.28 


250.99 




344.88 








71,907.73 


12,792.30 


285,023.98 


45,873.01 


13,646.36 


19,358.99 


20,057.44 


7,580.24 


36,822.04 
503.82 


8,131.48 


200,007.95 

4,994.95 

870.56 

6,116.52 
553.36 

1,488.50 
323.25 

3,232.58 
616.95 
6,056.05 
4,372.10 
6,797.02 
1,015.36 
21,775.00 

9,239.60 

19,951.00 

1,208.87 


28,976.73 
221.40 
261.99 

1,578.12 
340.87 
518.94 


8,932.52 


16,964.12 


10,658.85 


6,245.97 














5,422.41 
139.06 


625.49 


333.52 


463.47 


523.42 

39.68 

373.40 

297.99 

191.10 
421.48 

1,684.40 
408.03 
450.04 
409.85 

1,406.54 

1,317.64 
1,457.00 


218.43 
9.16 


1,236.37 






23.73 


157.71 










1,630.12 
712.43 


133.60 


692.34 
261.97 

797.48 

1,740.35 

391.30 

298.53 

1,884.42 

1,633.32 

3,140.00 


129.75 


46.98 


49.85 


3,066.06 




502.97 
65.17 
47.61 


622.54 

167.40 

55.95 


173.97 


3,684.60 
1,368.67 


408.53 


89.88 
19 50 


1,870.51 






9,504.11 

10,555.98 

5,783.00 


447.76 

1,512.84 

505.00 


972.93 

1,346.60 

830.00 


201.03 
197.13 
777.00 


95.49 
206.55 
427.00 
















82,299.18 


11,764.70 


288,619.62 


42,737.76 


13,161.07 


19,519.35 


19,639.42 


7,693.51 




1,027.60 




3,135.25 


485 . 29 




418.02 




10,391.45 


3,595.64 


160.36 


113.27 














1,645 

111 

13 


336 
80 

5 


4,293 
614 
132 


802 
173 

25 


382 
84 

5 


261 

68 

6 


506 

47 

3 


121 
39 

7 


1,769 


421 


5,039 


1,000 


471 


335 


556 


167 



362 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Thames- 
ville 
754 


Thedford 

577 


Thorndale 
P.V. 


Thorold 
5,068 


Tilbury 
1,996 


Population 






Earnings 
Domestic service 


$ c. 

4,003.41 
2,756.04 
2,111.24 
249.46 
1,191.00 


$ c. 

3,152.75 
1,796.45 
1,599.64 


$ c. 

1,432.95 
920.15 
254.32 


$ c. 

18,732.14 
6,486.84 

26,575.95 
2,901.88 
3,551.00 


$ c. 

6,539.15 

6,999.33 

6,888.96 

229.50 


Commercial light service 


Commercial power service 

Municipal power 


Street lighting 


1,035.00 


384.00 


1,580.22 


Merchandise 




Miscellaneous 


337.31 


50.90 


2.62 


388.87 


574.88 






Total earnings 


10,648.46 


7,634.74 


2,994.04 


58,636.68 


22,812.04 




Expenses 
Power purchased 


6,500.46 


4,712 96 


2,711.26 


45,747.53 
2,015.75 


14,547.09 




Substation maintenance 










Distribution system, operation and 
maintenance 


504.14 


108.30 


30.44 


2,969.32 


1,347.33 
38.92 


Line transformer maintenance 


Meter maintenance . 


157.43 




42.49 


276.45 


174 66 


Consumers' premises expenses 






Street lighting, operation and main- 
tenance 


235.47 


67.10 


47.00 


575.43 


273.37 


Promotion of business 




Billing and collecting. . 


206.63 

318.53 

38.50 


207 . 86 
81.85 
20.43 


55.34 
5.10 

17.75 


1,169.17 
878.65 
373.93 
372.70 


644.29 


General office, salaries and expenses . . 
Undistributed expenses 


529.70 
196.13 


Truck operation and maintenance . . . 




Interest 


280.22 
560.42 
735.00 


633.83 
851.48 
380.00 


75.56 

87.07 

230.00 


437.94 


Sinking fund and principal payments 
on debentures 




637.27 


Depreciation 


2,660.00 


1,121.00 


Other reserves 
















Total operating costs and fixed 
charges 


9,536.80 


7,063.81 


3,302.01 


57,038.93 


19,947.70 






Net surplus 


1,111.66 


570.93 




1,597.75 


2,864.34 


Net loss 


307.97 














Number of Consumers 
Domestic service 


219 

71 

8 


126 

40 

3 


62 

24 

1 


1,165 

191 

16 


420 


Commercial light service 


135 


Power service 


12 






Total 


298 


169 


87 


1,372 


567 







934 



HYDRO-ELECTRIC POWER COMMISSION 



363 



4< B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Tillson- 
burg 
3,351 


Toronto 
626,674 


Toronto 
Twp 


Trafalgar 

Twp. 
Area No. 1 


Trafalgar 

Twp. 
Area No. 2 


Walkerville 
10,681 


Wallaceburg 
4,343 


$ c 

14,962.86 
11,687.36 


$ c. 

3.747,121.17 
2,873,701.12 
3,167,430.03 
1.307,218.35 
531,411.66 


$ c. 

58,575.37 

13,743.10 

6,862.46 


$ c. 

14,152.49 
640.62 
520.19 


$ c. 
4,967.94 


$ c. 

104,317.38 

29,322.93 

127,701.63 


$ c. 

18,859.03 
10,687.00 


10,821.20 




49,402.59 


834.59 




1,913.90 


4,336.51 


4,975.20 






11,739.96 


4,167.00 


9.36 








485 . 15 


268,812.13 


1,460.57 


222.18 


96.87 


2,182.57 


719.62 


43,137.03 


11,895,694.46 


85,616.70 


15,535.48 


5,064.81 


275,264.47 


85,749.14 


27,345.49 
889.99 


6,493,300.17 
217,852.14 
247,239.28 

350,632.98 

37,083.99 

101,462.78 

295,659.39 

133,653.43 
178,555.92 
344,206.94 
365,072.53 
*97,936.46 


50,054.65 


7,888.00 


2,272. 2i5 


203,458.83 
5,385.14 
1,739.13 

3,890.69 
397.92 

2,728.77 
2,759.58 

2,578.80 
4,220.93 
6,074.17 
10,297.39 
7,614.83 
2.075.91 
8,673.39 

15,269.85 

16,322.00 


61,125.39 
248 . 00 












3,022.14 
267.53 


3,706.18 
468 . 63 
402.28 


2,134.48 


535.72 


1,914.39 


264.18 


68.70 




713.77 


44.95 




39.75 


549.98 


623.94 






836.01 








836.17 


756.15 


3,096.58 
4,607.09 
931.32 
1,504.60 
3,845.61 

5,133.95 

8,390.00 






2,201.19 


3,509.20 
355.47 
411.82 


1,414.13 
136.18 
223.20 
744.89 

928.70 

1,124.00 


549.27 
26.98 


2,341.53 

1,398 69 

740.73 


513.58 
1,032.76 


1,461,031.47 

1,237,415.80 

823,554.56 

2,740.83 


526.54 


2,730.08 
2,747.56 


3,199.00 
139.33 


293 . 00 


4,725.00 
88.15 














42,301.57 


12,387,398.67 


82,764.83 


14,662.28 


4,203.76 


293,487.33 


82,686.41 


835.46 




2,851.87 


873.20 


861.05 




3,062.73 




491,704.21 


18,222.86 














887 
223 


155,870 

25,980 

5,099 


1,875 

188 

23 


300 
2 
9 


136 


2.367 

317 

94 


1,020 

223 


30 




29 








1,140 


186,949 


2,086 


311 


136 


2,778 


1,272 



Includes $25,817.88 York Twp. debenture charges. 



364 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



NIAGARA 
SYSTEM— Continued 



Municipality 


Wardsville 
214 


Waterdown 
924 


Waterford 
1,168 


Waterloo 
8,563 


Watford 


Population 


956 






Earnings 
Domestic service 


$ c. 

1,124.76 
1,075.78 


$ c. 

5,645.12 

1,696.40 

1,468.02 

192.52 

901.50 


$ c. 

6,575.26 
1,766.76 
4,146.55 
276.32 
1,608.00 


$ c. 

58,827.49 

20,814.44 

24,058.94 

3,505.88 

7,499.04 

320.62 

149.94 


$ c. 
6,682.44 


Commercial light service 


3,237.14 


Commercial power service 


2,356 16 


Municipal power 




435.37 


Street lighting 


700.00 


1,344.96 


Merchandise 




Miscellaneous 


55.84 


11.60 


260.49 


335.79 






Total earnings 


2,956.38 


9,915.16 


14,633.38 


115,176.35 


14,391.86 


Expenses 
Power purchased . . 


1,936.53 


6,493.32 


11,933.09 


91,535.77 
1,401.68 
1,377.44 

3,743.64 

33.60 

1,035.65 


9,303 . 14 


Substation operation 


Substation maintenance 










Distribution system, operation and 

maintenance 

Line transformer maintenance 


51.30 


307.05 

49.65 

110.96 


331.30 


742.05 


Meter maintenance 




42.55 


138.48 


Consumers' premises expenses 






Street lighting, operation and main- 
tenance 


36.30 


60.01 


174.46 


762.00 


136.02 


Promotion of business 




Billing and collecting 




566.49 

145.52 
51.62 


576.00 

398.68 

26.93 


2,035.20 

3,383.28 

560.44 

984.87 

2,881.88 

4,892.31 

8,762.00 

128.00 


501.72 


General office, salaries and expenses. . 
Undistributed expenses 


182.83 


539.82 
60.06 


Truck operation and maintenance. . . 




129.36 


Interest 


299 . 17 

412.83 
235 . 00 


10.50 




124.17 


Sinking fund and principal payments 
on debentures 




712 62 


Depreciation 


791.00 


966 . 00 


752.00 


Other reserves 














Total operating costs and fixed 
charges 


3,153.96 


8,586.12 


14,449.01 


123,517.76 


13,139.44 






Net surplus 




1,329.04 


184.37 




1,252.42 


Net loss 


197.58 


8,341.41 












Number of Consumers 
Domestic service 


47 
21 


218 
33 

7 


306 

73 
11 


1,850 
249 

77 


284 


Commercial light service 


76 


Power service 


5 








Total 


68 


258 


390 


2,176 


365 







1934 



HYDRO-ELECTRIC POWER COMMISSION 



365 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Welland 
10,668 


Wellesley 
P.V. 


West Lome 
814 


Weston 
4,736 


Wheat ley 

724 


Windsor 
65,565 


Wood- 
bridge 
744 


Woodstock 
10,956 


$ c. 

49,514.12 

28,463.15 

60,726.86 

2,397.93 


$ c. 

2,706.26 
1,527.81 
1,773.00 


$ c. 

3,197.04 
1,483.82 
1,277.99 


$ c. 

39,599.41 
9,376.18 

31,984.50 

588.46 

7,610.13 


$ c. 

4,427.83 
2,717.93 
1,599.90 
461.86 
1,355.25 


$ c. 

503,381.88 

225,233.06 

170,277.85 

11,734.67 

76,109.88 


$ c. 

6,370 89 

1,632.47 

4,670.69 

410.44 

900.00 


$ c. 

72,772.34 

37,336.87 

46,357.30 

2,846.43 


10,559.01 
1,841. 15 


720.00 


1,010.00 


8,013.40 


3,384.77 


12.76 


55.57 


899.56 


92.66 




21.48 


3,554.32 








156,886.99 


6,739.83 


7,024.42 


90,058.24 


10,655.43 


986,737.34 


14,005.97 


170,880.66 


94,636.78 
4,898.27 


5,208.81 


3,970.10 


68,789.37 


6,401.77 


589,905.81 

15,910.88 

3,473.27 

12,577.85 

1,844.42 

12,278.03 

22,628.07 

13,375.44 
18,016.56 
31,162.17 
27,751.66 
17,147.22 
14,675.38 
65,640.56 

85,361.15 

64,790.00 


10,143.24 


131,319.41 

2,724.48 


90.61 






169.36 

4,658.02 
332.01 
830.30 






83.45 


7,144.69 
132.46 


31.44 


150.33 


498.49 

24.70 

146.44 


418.69 


5,138.27 
549.12 


2,985.44 


52.40 


32.16 




1,273.79 


263.90 






1,121.71 


36.84 


117.24 


961.09 


275.56 


151.28 


2,197.71 
267.30 


4,103.83 




464.70 

169.62 

15.00 


641.10 

2,930.44 

582.05 

454.68 

2,216.03 

3,016.95 

4,830.00 


328.18 
193.40 

43.73 




3,716 79 


9,018.64 
943.33 


431.05 
26.03 


563.59 


4,999.07 
1,651.43 


1,597.40 




817 35 


14,131.55 

9,991.62 

12,213.53 


138.84 
517.94 
313.00 


328.57 
257.07 
593.00 


485 . 15 
603.65 
588.00 


480.66 
291.59 
800.00 


3,424.55 

2,682.05 

11,775.00 


















163,273.76 


6,756.35 


6,097.79 


90,411.40 


9,589.07 


996,538.47 


12,849.05 


172,619.77 






926.63 




1,066.36 




1,156.92 




6,386.77 


16.52 


353.16 


9,801.13 


1,739.11 












2,271 

438 

83 


121 
44 

5 


187 
49 

4 


1,248 

179 

30 


171 

57 
4 


14,605 

2,263 

318 


244 

50 

6 


2,904 

443 

86 


2,792 


170 


240 


1,457 


232 


17,186 


300 


3,433 



366 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



NIAGARA 
SYSTEM— Concluded 



Municipality 


Wyoming 
482 


*York Twp. 


Zurich 
P.V. 


NIAGARA 


Population 


SYSTEM 
SUMMARY 






Earnings 
Domestic service 


$ c. 

2,647.88 

1,582.19 

152.10 


$ c. 

558,465.55 
64,625.08 
89,734.45 


$ c. 

3,176.37 
1,860.84 


$ c. 

9,263,031.01 
4,987,219.71 
7,326,323.77 
1,646,884.64 
1,389,025.47 
9,301 81 
402,652.28 


Commercial light service 


Commercial power service 


Municipal power 




Street lighting 


765.00 


49,614.79 


693 . 00 


Merchandise 


Miscellaneous 


15.28 


17,073.89 


117.72 




Total earnings 


5,162.45 


779,513.76 


5,847.93 


25,024,438 69 






Expenses 
Power purchased 


3,201.18 


379,460.71 


4,601.35 


15,413,215.29 
404,570.48 


Substation operation 


Substation maintenance 




27,860.54 

20,607.93 
3,984.68 
6,128.79 

25,117.30 

8,066.62 

3,031.51 

37,034.11 

34,822.33 

35,912.94 




281,366.35 


Distribution system, operation and 
maintenance 


92.89 


232.42 


722,383.72 


Line transformer maintenance 


71,396.55 


Meter maintenance 




67.55 


230,149.55 


Consumers' premises expenses 




353,539.08 


Street lighting, operation and main- 
tenance 


58.11 


80.10 


271,828.92 


Promotion of business. . 


244,030.17 


Billing and collecting 


166 . 00 
167.87 


183.94 
92.69 
20.11 


673,185.33 


General office, salaries and expenses . . 
Undistributed expenses 


740,249.97 
268,362.00 


Truck operation and maintenance . . . 




84,066 . 24 


Interest 


150.56 
750.03 
385.00 


199,599.83 
21,824.38 
20,428.00 


215.83 
174.67 
372.00 


2,179,869.71 


Sinking fund and principal payments 
on debentures 


2,108,108.41 


Depreciation 


1,604,015.63 


Other reserves 


26,493.60 












Total operating costs and fixed 
charges 


4,971.64 


823,879.67 


6,040.66 


25,676,831.00 






Net surplus 


190.81 








Net loss 


44,365.91 


192.73 


652,392.31 








Number of Consumers 
Domestic service 


132 

50 

2 


19,397 

1,037 

150 


124 
46 


366,817 


Commercial light service 


58,040 


Power service . . 


10,590 








Total 


184 


20,584 


170 


435,447 







*For year ended December 31, 1932. Included in Toronto figures. Not added in Summary. 



934 



HYDRO-ELECTRIC POWER COMMISSION 



367 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



GEORGIAN BAY 
SYSTEM 



Alliston 
1,379 


Arthur 
1,037 


Barrie 

7,455 


Beaverton 
960 


Beeton 
584 


Bradford 
1,009 


Brechin 
P.V. 


Cannington 
851 


$ c. 

8,513.19 

4,492.67 

1,665.75 

812.96 


$ c 

4,569.26 
3,636.14 
1,636.55 
576.53 
1,748.00 


$ c. 

52,465.38 

29,741.26 

15,417.24 

983.33 

5,961.25 


$ c. 

6,038.34 
2,354.80 
1,080.55 


$ c 

3.594.5C 
2,482. 4C 
1,852.91 


$ c 

6,341.25 

3,006.67 

2,654.76 

336.89 

1,273.00 

60.43 

60.67 


$ c 

971.23 
1,074.32 
1,077.29 


$ c. 

5,185.51 

2,337.93 

619.89 


2,070.00 


1,286.52 


1,185.00 


576.00 


1,022.00 


28.64 




1,302.38 


793 . 85 


9.66 


28.53 


80.75 








17,583.21 


12,166.48 


105,870.84 


11,554.06 


9,124.47 


13,733.67 


3,727.37 


9,246.08 


11,574.06 


9,561.78 


76,201.02 
894.47 


7,686.41 


7,116.40 


8,416.51 


2,641.63 


6,682.04 
















623.40 


553.34 


2,870.39 

493 . 80 

1,485.18 


991.21 


42.63 


225.49 


302.50 


586.78 






























339.40 


89.55 


1,020.39 


169.02 


193.93 


57.23 


42.09 


149.70 
10.60 


822.79 




3,102.46 
1,122.64 
1,000.07 
583.59 
3,048.82 

2,691.38 

7,023.00 

300.00 






634.56 

76.17 

254.61 






135.55 
85.81 


378.13 


607 . 09 


408.38 


143.77 


568.93 














1,765.08 
1,390.41 
1,332.00 


1,155.08 
720.71 
906 . 00 


366.62 

580.34 

1,101.00 


534.07 
447.01 
579.00 


1,176.50 
836.30 
825.00 


219.05 

98.29 

138.00 


505.57 
608.17 
652.00 
















18,068.50 


13,364.59 


101,837.21 


11,501.69 


9,321.42 


12,502.37 


3,585.33 


9,763.79 






4,033.63 


52.37 




1,231.30 


142.04 




485 . 29 


1,198.11 


196.95 


517.71 














351 

201 

16 


185 

86 

4 


2,011 

407 

45 


303 

63 

9 


124 
37 

5 


223 

63 

8 


42 

28 

4 


246 
71 
10 


568 


275 


2,463 


375 


166 


294 


74 


327 



368 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



GEORGAIN BAY 
SYSTEM— Continued 



Municipality 

Population 


Chatsworth 
272 


Chesley 
1,789 


Coldwater 
626 


Colling- 
wood 

5,788 


Cooks- 
town 
P.V. 






Earnings 
Domestic service 


$ c. 

1,590.06 

1,304.24 

583.08 


$ c. 

8,902.79 
4,106.77 
8,451.38 

991.04 

1,596.00 

5.02 

664.48 


$ c. 

2,884.70 
1,746.74 

2,557.43 


$ c. 

26,122.58 
9,951.70 

16,342.67 
1,895.68 
3,013.33 


$ c. 
2,479.81 


Commercial light service 


1,264.87 


Commercial power service 


911.92 


Municipal power 




Street lighting 


492.00 


571.00 


1,008.00 


Merchandise 




Miscellaneous 


89.84 


209.01 


1,515.88 


46.37 






Total earnings 


4,059.22 


24,717.48 


7,968.88 


58,841.84 


5,710.97 






Expenses 

Power purchased 

Substation operation 


2,565.47 


18,031.74 


6,811.92 


49,999 . 25 


2,686.76 


Substation maintenance 








39.50 

1,789.46 

70.59 

677.75 




Distribution system, operation and 
maintenance 


189.73 


672.90 


298 . 24 


168.78 


Line transformer maintenance 




Meter maintenance 




160.25 






Consumers' premises expenses . . 








Street lighting, operation and main- 
tenance 


59.22 


188.20 


63.00 


239.71 

6.22 

2,866.05 

2,913.18 

616.91 

318.33 

300.00 


86.48 


Promotion of business 




Billing and collecting 




386.41 
612.45 
122.07 
24.50 
404.81 

1,934.61 

1,206.00 






General office, salaries and expenses. . 
Undistributed expenses . . 


327.53 


497 . 22 


270.22 


Truck operation and maintenance. . . 








Interest. 


282.18 
216.19 
262.00 


217.73 
267.27 
531.00 


444 . 62 


Sinking fund and principal payments 
on debentures . . 


282.86 


Depreciation .... 


3,750.00 


503.00 


Other reserves 
















Total operating costs and fixed 
charges 


3,902.32 


23,743.94 


8,686.38 


63,586.95 


4,442.72 






Net surplus 


156.90 


973.54 






1,268.25 


Net loss 


717.50 


4,745.11 












Number of Consumers 
Domestic service 


73 
29 

1 


420 
97 
19 


131 

54 

4 


1,420 

269 

53 


96 


Commercial light service 


27 


Power service 


5 






Total 


103 


536 


189 


1,742 


128 







1934 



HYDRO-ELECTRIC POWER COMMISSION 



369 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Creemore 

587 


Dundalk 
647 


Durham 
1,800 


Elmvale 
P.V. 


Elm wood 
P.V. 


Flesherton 
491 


Grand 
Valley 

587 


Graven - 
hurst 
1,830 


$ c. 

3,579.49 
1,808.96 
1,102.80 


$ c. 

2,604.62 
2,200.70 
2,240.17 


$ c. 

6,477.31 
4,139.84 
5,857.92 
759.79 
1,935.00 


$ c. 

2,673.02 

1,728.30 

2,618.79 

140.33 

662.31 


$ c. 

1,185.37 

586.45 

1,339.14 


$ c. 

2,686.74 

1,768.58 

226.29 


' $ c. 

3,467.61 
1,799.23 
1,975.40 


$ c. 

8,580.86 
6,087.91 
7,202.34 

575.67 


673.63 


1,220.00 


529.00 


621.00 


936.00 


2,096.24 


7.00 


165.00 


772.47 


86.34 


36.96 


30.54 


138.21 




7,171.88 


8,430.49 


19,942.33 


7,909.09 


3,676.92 


5,333.15 


8,316.45 


24,543.02 


5,789.05 


6,224.88 


15,726.37 


6,373.35 


2,541.79 


3,547.92 


5,796.19 


16,208.46 


















200.17 


627.53 


- 795.45 


617.01 


12.50 


36.47 


117.92 


1,227.17 
67.78 






28.65 


17.35 








138.03 














62.84 


124.31 


166.19 


30.18 


13.10 


26.55 


66.00 


572.91 
10.47 






1,043.82 
494.55 
248.10 
267.18 
344.40 

1,296.91 

1,108.00 


210.00 
53.21 
23.50 








431.11 


252.65 


611.30 


194.93 


384.97 


529.83 


1,455.67 
275.96 












255.67 


129.91 
504.36 
387.00 


67.07 
356.35 
432.00 


175.81 
279.55 
600.00 


215.68 
426.08 
238.00 


398.72 
264.97 
336.00 


213.48 
759.64 
523.00 


722.51 
2,088.21 
1,700.00 

225.00 


















7,325.98 


8,443.44 


21,519.62 


8,379.96 


3,642.08 


4,995.60 


8,006.06 


25,378.95 










34.84 


337.55 


310.39 




154.10 


12 95 


1,577.29 


470.87 


835.93 












157 

52 

3 


157 

69 

4 


422 

109 

11 


150 
59 

8 


58 
19 

1 


139 

48 

2 


156 

48 
4 


464 

115 

12 


212 


230 


542 


217 


78 


189 


208 


591 



370 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



GEORGIAN BAY 
SYSTEM— Continued 



Municipality 


Hanover 
3,036 


Holstein 
P.V. 


Huntsville 
2,507 


Kincardine 
2,429 


Kirkfield 


Population 


P.V. 






Earnings 
Domestic service 


$ c. 

18,407.63 
6,627.47 

17,684.10 

309.97 

3,488.16 


$ c. 

1,479.27 
570.60 
238.59 

"490.00 


$ c. 

10,973.86 
7,418.16 

11,515.00 
1,400.00 
2,675.00 


$ c. 

13,824.32 
6,956.57 
9,058.53 
1,444.90 
4,022.50 


$ c. 
749.21 


Commercial light service 


1,156.47 


Commercial power service 




Municipal power 




Street lighting 


460.00 


Merchandise 




Miscellaneous 


1,540.64 




682.94 


30.18 








Total earnings 


48,057.97 


2,778.46 


34,664.96 


35,337.00 


2,365.68 






Expenses 
Power purchased 


31,066.93 


1,955.95 


29,980.04 


25,823.72 
336.94 


1,423.29 


Substation operation 




Substation maintenance 










Distribution system, operation and 
maintenance 


1,776.72 

36.37 

114.89 


51.05 


2,322.42 
19.45 
49.10 


1,258.69 


204.62 


Line transformer maintenance 




Meter maintenance .... 








Consumers' premises expenses 




112.01 
263 . 10 




Street lighting, operation and main- 
tenance 


174.81 


14.92 


230.71 
96.10 
507.34 
1,241.20 
719.78 
186.31 
206 . 88 

686.36 

1,080.00 


3.48 


Promotion of business 




Billing and collecting 


1,097.39 
634.21 
491.15 
141.94 

2,386.90 

5,282.60 
3,233.00 


" 169 '. 24 


678.44 
567.61 
377.31 
259.97 
2,114.88 

3,167.80 

2,075.00 




General office, salaries and expenses . . 
Undistributed expenses 


35.05 


Truck operation and maintenance. . . 
Interest 






214.07 
213.79 
109 . 00 


243.62 


Sinking fund and principal payments 
on debentures 


347.88 


Depreciation 


206 . 00 


Other reserves 
















Total operating costs and fixed 
charges 


46,436.91 


2,728.02 


37,325.69 


37,035.47 


2,463.94 






Net surplus . . 


1,621.06 


50.44 








Net loss 


2,660.73 


1,698.47 


98.26 










Number of Consumers 
Domestic service 


726 

119 

20 


54 
18 

1 


556 

123 

9 


596 

120 

19 


27 


Commercial light service 


20 


Power service 








Total 


865 


73 


688 


735 


47 







934 



HYDRO-ELECTRIC POWER COMMISSION 



371 



"B" -Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Lucknow 
1,082 


Markdale 

774 


Meaford 
2,707 


Midland 
6,808 


Mildmay 
694 


Mount 
Forest 
1,821 


Neustadt 
465 


Orangeville 
2,785 


$ c. 

6,845.31 
2,998.23 
3,499.49 

517.52 


$ c. 

3,571.87 

2,580.48 

1,048.02 

81.00 

900 . 00 


$ c. 

12,262.19 

6,475.28 

3,878.90 

761.52 

3,219.19 

2.58 

765.66 


$ c. 

35,287.78 

13,714.77 

47,445.51 

3,029.05 

6,175.84 


$ c. 

2,967.88 

2,024.23 

719.27 


$ c. 

7,571.59 
5,190.17 
3,040.59 
1,214.91 
2,370.00 


$ c. 

2,019.90 

1,357.97 

63.33 


$ c. 

14,312.27 
8,697.09 
6,926.65 
1,264.70 


1,522.50 


659.56 


975 . 00 


3,760.20 
16.61 


187.01 






21.06 


262.75 




168.65 












15,570.06 


8,181.37 


27,365.32 


105,652.95 


6,392.00 


19,650.01 


4,416.20 


35,146.17 


10,946.31 


5,784.99 


17,537.97 


80,691.58 

1,993.84 

207.58 

2,373.26 

78.54 

781.45 


3,054.84 


15,632.99 


3,441.78 


26,032.43 
















363.49 


22.44 


953.55 
34.50 
40.07 


149.64 


469.98 


28.92 


1,315.31 






229.09 


159.45 




49.55 






10 70 


122.76 


117.48 


209.00 


676.98 
875.21 
2,179.46 
2,409.97 
2,008.55 
315.28 
2,555.03 

5,449.28 

9,512.00 


42.80 


320.62 


69.95 


485.42 






579.35 

1,749.10 

468.22 

121.52 

1,971.51 

1,018.24 

1,340.00 




817.89 
386.50 
119.25 
39.05 
713.66 

635.63 

1,310.00 




1,418.12 


876.03 


439.21 


375.06 


205.61 


35.40 
101 02 












739.41 
962.87 
732.00 


375.21 
306.55 
576.00 


408.86 
408.27 
206.00 


921.48 
986.86 
560.00 


656.87 
2,307.85 
1,916.00 


















14,742.87 


7,621.88 


26,023.03 


112,108.01 


4,874.56 


20,605.02 


6,214.60 


34,328.67 


827.19 


559.49 


1,342.29 




1,517.44 






817.50 




6,455.06 


955.01 


1,798.40 














252 
79 

7 


187 
79 
10 


638 

138 

17 


1,564 
227 

55 


140 
47 

2 


447 
160 


96 

28 
2 


654 
161 

27 


338 


276 


793 


1,846 


189 


618 


126 


842 



372 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



GEORGIAN BAY 
SYSTEM— Continued 



Municipality 


Owen 
Sound 
12,803 


Paisley 

732 


Penetang- 

uishene 

4,046 


Port 
Elgin 
1,230 


Port 


Population 


McNicoll 
928 






Earnings 
Domestic service 


$ c. 

60,161.55 
33,647.11 
37,592.84 


$ c. 

3,937.95 
2,679.61 
1,155.09 


$ c. 

11,560.03 

4,471.57 

10,183.08 

1,752.93 

2,149.00 

17.81 

77.30 


$ c. 

8,046.31 
4,123.07 
3,400.92 
886.65 
2,103.79 


$ c. 

3,643.06 
801 37 


Commercial light service 


Commercial power service 




Municipal power 




Street lighting 


11,181.23 
279.45 
131.16 


1,408.00 


927 50 


Merchandise 




Miscellaneous 


143.99 


315.46 








Total earnings 


142,993.34 


9,324.64 


30,211.72 


18,876.20 


5,371.93 




Expenses 

Power purchased 

Substation operation 


106,952.41 
4,695.16 


6,583.66 


21,327.95 
643.51 
103.71 

1,438.26 
106.25 

222.53 


8,730.36 


3,295.61 


Substation maintenance 








Distribution system, operation and 
maintenance 


5,903.00 

548.54 

1,059.77 


128.90 


942.49 


383.69 


Line transformer maintenance 




Meter maintenance 




44.54 




Consumers' premises expenses 






Street lighting, operation and main- 
tenance 

Promotion of business. . . . . . 


2,614.07 


105.84 


248 . 20 


217.80 


120.84 


Billing and collecting 


5,216.40 

5,646.34 

2,647.53 

730.57 

516.18 




942.21 

686 . 68 

270.72 

142.90 

1,122.97 

1,655.05 

2,817.00 


689.37 

86.98 

138.58 

272.95 

1,981.31 

1,400.40 

826.00 




General office, salaries and expenses. . 
Undistributed expenses 


472.50 


120.75 


Truck operation and maintenance. . . 
Interest . . 






618.43 
742.95 
506.00 


186.79 


Sinking fund and principal payments 
on debentures . . 


484 . 43 


Depreciation 


6,920.00 


390.00 


Other reserves 
















Total operating costs and fixed 
charges 


143,449.97 


9,158.28 


31,727.94 


15,330.78 


4,982.11 






Net surplus 




166.36 




3,545.42 


389.82 


Net loss 


456.63 


1,516.22 












Number of Consumers 
Domestic service 


3,257 
576 
115 


186 

55 
4 


599 
99 

27 


373 

86 

8 


197 


Commercial light service 


31 


Power service 








Total 


3,948 


245 


72.5 


467 


228 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



373 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Port Perry 
1,130 


Priceville 
P.V. 


Ripley 
451 


Rosseau 
251 


Shelburne 
1,064 


South- 
ampton 
1,520 


Stayner 
1,042 


Sunder- 
land 
P.V. 


$ c. 

6,660.96 
2,805.22 

2,528.58 


$ c. 

675.10 
332.43 


$ c. 

3,363.35 
1,858.53 


$ c. 

2,871.74 
927.90 


$ c. 

5,384.95 

3,309.71 

1,591.58 

578.43 

960 . 00 


$ c. 

8,144.39 
3,487.74 
2,137.68 
1,231.34 
2,106.92 


$ c. 

4,391.43 
2,642.06 
2,375.56 


$ c. 

2,335.55 

1,699.71 

55.85 


372.11 










1,500.00 


560.00 


1,266.00 


1,240.00 


1,224.00 


706.67 


894 . 65 


11.55 


4.49 


141.67 


233.65 


150.44 


328.64 


50.00 


14,761.52 


1,579.08 


6,492.37 


5,181.31 


12,058.32 


17,258.51 


10,961.69 


4,847.78 


9,873.21 


1,139.68 


4,204.77 


3,550.01 


9,554.83 


8,228.69 


8,245.44 


3,473.99 


















901.67 


15.24 


' 35.50 


206.93 

45 


925.20 


1,109.33 

2.10 

50.85 


549.12 


170.22 






















1.82 
51.87 






100.25 


21.76 


66.72 


24.69 


148.14 


142.22 


21.37 








131.81 

7.52 
15.75 


553.89 
74.74 


863.40 
233.93 
235.85 
307.68 
1,428.87 

1,100.31 

701.00 


566.06 

112.57 

72.92 




820.37 


46.61 


419.48 


321.77 


15.00 










954.68 
747.50 


454.94 
328.21 
177.00 


648 . 74 
381.78 
426.00 


956.15 


349.69 

1,321.85 

945 . 00 


176.21 

1,085.53 

806 . 00 


222.84 
318.58 


821.00 


288 . 00 


278.00 


















14,233.68 


2,183.44 


6,182.99 


5,181.31 


13,778.89 


14,410.15 


11,756.07 


4,806.77 


527.84 


604.36 


309.38 






2,848.36 




41.01 






1,720.57 


794.38 














300 
75 
10 


31 
12 


128 
44 


61 
21 


285 
83 
11 


384 
83 
13 


257 
S3 
12 


112 

42 

1 












385 


43 


172 


82 


379 


480 


352 


155 



374 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



GEORGIAN BAY 
SYSTEM— Concluded 



Municipality 


Tara 
491 


Tees water 

805 


Thornton 
P.V. 


Tottenham 
546 


Uxbridge 
1,506 


Population 






Earnings 
Domestic service 


$ c. 

2,632.36 

1,306.32 

690.33 


$ c. 

4,642.20 

2,219.12 

939 . 09 

180.00 

1,402.00 


$ c. 

1,151.90 
637.95 
243 . 14 


$ c. 

3,227.06 

2,100.62 

166.00 

194.99 

1,225.08 


$ c. 
8,019.21 


Commercial light service 


3,255.12 


Commercial power service 


931.13 


Municipal power 




Street lighting 


1,260.00 


880.00 


1,743.00 


Merchandise 




Miscellaneous 


6.04 


190.45 


2.79 


3.45 


405 . 78 






Total earnings 


5,895.05 


9,572.86 


2,915.78 


6,917.20 


14,354.24 






Expenses 
Power purchased 


3,432.35 


6,115.52 


1,481.77 


5,087.62 


10,902.64 






Substation maintenance 












Distribution system, operation and 
maintenance 


175.70 


62.41 


46.75 


322.35 


585.46 


Line transformer maintenance 




Meter maintenance 












Consumers' premises expenses 












Street lighting, operation and main- 
tenance 


37.10 


69.55 


17.32 


105.46 


229.30 


Promotion of business 




Billing and collecting 












General office, salaries and expenses. . 
Undistributed expenses 


486.60 


543 . 08 


81.93 


192.20 


785 . 19 


Truck operation and maintenance. . . 












Interest 


354.98 
942.80 
520.00 


993 . 03 

1,132.80 

690.00 


306.86 
425.02 
307.00 


445.71 
383.81 
410.00 


772.92 


Sinking fund and principal payments 
on debentures 


973.67 


Depreciation 


665 . 00 


Other reserves 
















Total operating costs and fixed 
charges 


5,949.53 


9,606.39 


2,666.65 


6,947.15 


14,914.18 






Net surplus 






249 . 13 






Net loss 


54 . 48 


33.53 


29.95 


559.94 








Number of Consumers 
Domestic service 


127 

36 

4 


195 

55 
7 


55 

18 

4 


128 

54 

4 


354 


Commercial light service 


91 


Power service 


10 






Total 


167 


257 


77 


186 


455 







1934 



HYDRO-ELECTRIC POWER COMMISSION 



375 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Victoria 

Harbor 

1,171 


Walker- 
ton 
2,340 


Waubau- 
shene 
P.V. 


Wiarton 
1,911 


Winder- 
mere 

135 


Wingham 
1,842 


Wood- 
ville 
414 


GEORGIAN 

BAY 

SYSTEM 

SUMMARY 


$ c. 

2,894.43 

839 . 09 

47.34 


$ c. 

15,041.12 

7,683.67 

4,262.46 

657.15 

2,369.55 

27.87 

85.90 


$ c. 

2,221.71 

630.34 

604 . 89 

98.29 

405 . 00 


$ c. 

8,800.93 
5,782.47 
1,820.13 
1,403.92 
2,300.00 


$ c. 

2,241.87 
1,095.71 


$ c. 

12,512.87 

6,933.68 

8,308.52 

480.35 

3,423.00 

669.15 

470.69 


$' c. 

2,291.30 

1,068.90 

770.18 


$ c. 

478,039.49 
249,726.99 
262,336.64 


124.20 




25,056.15 


702.00 


455.00 


532.00 
"298.83 


105,222.97 
1,078.92 


1.10 


110.56 




10.13 


13,794.19 








4,608.16 


30,127.72 


4,070.25 


20,107.45 


3,802.71 


32,798.26 


4,961.21 


1,135,255.35 


3,112.17 


16,105.10 


2,153.97 


14,375.20 


2,026.84 


16,384.56 
1,746.47 


3,193.34 


805,087.51 
10,310.39 














350.79 


50.09 


1,885.83 

70.00 

112.30 


113.17 


408.39 


168.92 


2,549.36 


246.32 


43,563.46 
1,528.37 






126.45 




295 . 20 




5,842.45 










124.53 


116.06 


203.80 


75.79 


212.13 


29.67 


355.92 


34.45 


11,862.35 
998.60 




1,468.08 

1,117.42 

161.88 

285.56 

3,054.73 

2,000.55 

1,324.00 




990.90 

1 279.86 

107.50 

92.77 

1,658.63 

1,131.07 

700.00 


159.41 
29.18 
36.75 


577.04 
714.42 
451.76 
139.18 
2,459.05 

3,901.39 

2,797.00 


"32l'03 


28,933.76 


353.29 


324.35 


35,441.35 
11,051.55 








4,499.95 


81.75 
463.21 
390.00 


48.94 
256.21 
264 . 00 


*719.36 
282.00 


187.88 
231.73 
223.00 


46,897.73 

59,232.44 

71,460.00 

525.00 


















4,566.57 


27,789.25 


3,236.43 


20,082.90 


3,452.13 


32,371.35 


4,437.75 


1,137,710.23 


41.59 


2,338.47 


833.82 


24.55 


350.58 


426.91 


523.46 






2,454.88 


















167 

28 

2 


535 

134 

17 


134 

25 
3 


349 

103 

13 


48 
9 


504 
143 

24 


110 
31 

2 


22,141 

5,287 
699 








197 


686 


162 


465 


57 


671 


143 


28,127 



'Includes debenture accrual. 



376 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



EASTERN ONTARIO 
SYSTEM 



Municipality .... 


Alexandria 
2,340 


Apple Hill 
P.V. 


Athens 

582 


Bath 
350 


Belleville 


Population 


14,059 






Earnings 
Domestic service 


$ c. 

7,390.51 
4,173.80 
3,174.90 
1,634.41 
2,640.00 


$ c. 

1,080.88 
827.60 
279.49 


$ c. 

3,966.74 
1,813.42 
1,127.76 


$ c. 

1,441.86 
718.97 


$ c. 
76,682.94 


Commercial light service 


48,107.35 


Commercial power service 


34,529.14 


Municipal power 




7,709.49 


Street lighting. . 


559.75 


1,250.00 


714.00 


11,655.86 


Merchandise 


544.70 


Miscellaneous 


355.93 


3. 38 


19.19 


16.03 


885.68 






Total earnings 


19,369.55 


2,751.10 


8,177.11 


2,890.86 


180,115.16 






Expenses 
Power purchased 


12,609.86 


1,726.10 


4,738.92 


2,105.43 


128,674.13 


Substation operation 




Substation maintenance 












Distribution system, operation and 
maintenance 


885 . 29 

122.42 

152.13 

3.03 

299.66 


52.10 


87.12 

2.24 

19.79 


8.18 


3,914.42 


Line transformer maintenance 


288.26 


Meter maintenance 




2,889.51 


Consumers' premises expenses 




325.52 


Street lighting, operation and main- 
tenance 


58.01 


108.87 




1,399.56 


Promotion of business 




1,185.78 


Billing and collecting 


912.85 
400.91 
105.51 








4,245.76 


General office, salaries and expenses. . 
Undistributed expenses 


234.39 


174.62 
15.00 


131.73 


7,098.63 
1,762.82 


Truck operation and maintenance. . . 






214.16 


Interest 

Sinking fund and principal payments 
on debentures ... 


1,466.06 
2,498.40 
1,298.00 


222.47 
303.95 
159.00 


674.09 
497.41 
437.00 


485.30 
215.09 
164.00 


1,701.00 
6,000.00 


Depreciation 


5,251.00 


Other reserves 
















Total operating costs and fixed 
charges 


20,754.12 


2,756.02 


6,755.06 


3,109.73 


164,950.55 


Net surplus 






1,422.05 


218.87 


15,164.61 


Net loss . . 


1,384.57 


4.92 










Number of Consumers 
Domestic service 


295 
92 
14 


46 
18 

1 


140 
50 


31 
16 


3,004 


Commercial light service 

Power service 


555 
90 








Total 


401 


65 


191 


47 


3,649 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



377 



4 'B"- Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Bloom field 
614 


Bowman- 
ville 
3,641 


Brighton 
1,413 


Brockville 
9,615 


Cardinal 
1,305 


Carleton 
Place 
4,272 


Chesterville 
950 


$ c. 

2,713.31 
807 . 79 
497 . 13 


$ c. 

30,135.04 
10,239.80 
40,064 . 74 


$ c. 

10,102.13 
4,619.79 
2,051.65 


$ c. 

45,903.86 

25,015.27 

30,457.81 

5,566.61 

8,772.50 


$ c. 

6,257.90 

1,943.40 

551.64 


$ c. 

18,946.89 
9,355.65 

23,803.35 
1,930.94 
4,385.00 


$ c. 

5,396.47 
2,298 21 
2,562.57 


720.00 


4,057.17 


1,644.00 


1,066.00 


1,032.00 
241.05 


5.46 


620.16 


77.59 


6,450.70 


4.44 


2,203.81 


506 . 08 


4,743.69 


85,116.91 


18,495.16 


122,166.75 


9,823.38 


60,625.64 


12,036.38 


4,139.16 


63,015.45 


10,233.57 


75,024.19 

5,415.00 

498 . 09 

1,793.65 

418.09 

1,957.13 


5,566.26 


38,341.57 


8,042.22 










171.79 

1,765.85 

65.30 

176.60 




63.90 


2,291.59 

288.34 

472.34 

4.10 

610.53 

8.35 

1,943.55 

2,515.67 

979.05 


2,722.31 

140.00 

262.53 

48.95 

182.99 
64.96 

8 15,. 02 
1,487.67 

733.98 

350.94 
1,140.51 

851.76 

574.00 


823.14 

45.00 

4.80 

1.48 

176.85 


977.58 


157.26 








100.00 


1,871.14 
198.92 
2,159.94 
5,082.23 
1,928.91 
608.87 
3,935.46 

7,249.18 

8,191.00 


298.48 


180.00 






1,557.25 

3,373.66 

276.02 

648.34 

2,684.61 

2,409.68 

1,974.00 

500.00 


409.75 


201.76 


499 . 27 


413.89 








486.48 
403.82 
486.00 


2,965.14 
2,309.30 
1,493.00 


703.50 
500.13 
329.00 


106.24 
190.90 
597.00 














6,038.38 


78,896.41 


19,609.19 


116,331.80 


8,649.43 


54,243.15 


10,917.58 




6,220.50 




5,834.95 


1,173.95 


6,382.49 


1 118 80 


1,294.69 


1,114.03 
















148 
26 

4 


1,045 

173 

29 


537 

95 

9 


2,541 

438 

67 


286 
50 

2 


938 

178 

18 


227 

65 

3 


178 


1,247 


641 


3,046 


338 


1,134 


295 



378 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



EASTERN ONTARIO 
SYSTEM— Contin ued 



Municipality 


Cobourg 
5,619 


Colborne* 
977 


Deseronto 
1,418 


Finch 
383 


Hastings 
707 


Population 






Earnings 
Domestic service. . 


$ c. 

30,913.56 

18,424.66 

22,556.07 

5,388.15 

5,584.04 


$ c. 

4,517.68 
3,112.69 
357.94 
233.32 
1,287.00 
128.24 
181.67 


$ c. 

6,416.69 
2,254.49 
1,171.51 

856.70 

1,791.96 

28.30 

228.2-4 


$ c. 

1,941.99 

1,549.09 

700.39 


$ c. 
3,997 82 


Commercial light service 


1,684.61 


Commercial power service 


759 66 


Municipal power 




Street lighting 


502.50 


1,550.92 


Merchandise 




Miscellaneous 


1,120.51 


122.96 


236.43 






Total earnings. 


83,986.99 


9,818.54 


12,747.89 


4,816.93 


8,229.44 




Expenses 
Power purchased 


54,650.04 


4,171.90 


7,090.74 


2,686.18 


3,443.48 


Substation operation 




Substation maintenance 












Distribution system, operation and 
maintenance 


1,922.74 
613.81 
591.35 
210.47 

684.56 

5.63 

2,404.41 

3,940.15 

1,594.58 

124.75 
4,763.05 

3,291.15 

2,207.00 


867.06 
60.32 
72.79 


1,716.77 

8.96 

231.62 


93.65 


152.28 


Line transformer maintenance 




Meter maintenance 




8.39 


Consumers' premises expenses 

Street lighting, operation and main- 
tenance 






108.69 


245.36 


28.90 


85.08 


Promotion of business . . 




Billing and collecting 


' 1,237.79 

40.34 

220.66 

940.11 


304.93 

701.75 

82.60 






General office, salaries and expenses. . 
Undistributed expenses 


213.48 


388.46 
27.00 


Truck operation and maintenance. . . 
Interest. . . 






574.36 
487.88 
350.00 


374.58 
254.64 
253.00 


1,155.40 


Sinking fund and principal payments 
on debentures 


635.39 


Depreciation 


188.00 


419.00 


Other reserves 
















Total operating costs and fixed 
charges 


77,003.69 


7,907.66 


11,794.97 


3,904.43 


6,314.48 






Net surplus 


6,983.30 


1,910.88 


952.92 


912.50 


1,914.96 


Net loss 
















Number of Consumers 
Domestic service 


1,114 

141 

45 


218 
79 

3 


291 
66 
11 


78 
31 

1 


166 


Commercial light service 


49 


Power service 


5 






Total 


1,300 


300 


368 


110 


220 







*Eleven months operation. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



379 



1 'B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Havelock 
1,096 


Kemptville 
1,227 


Kingston 
23,260 


La Icefield 
1,303 


Lanark 
636 


Lancaster 
601 


Lindsay 
7,109 


$ c. 

6,089.60 
2,087.16 
2,881.48 


$ c. 

7,000.28 
4,387.41 
4,620.72 


$ c. 

108,782.64 
72,441.72 
87,493.96 
10,776.04 
25,486.08 


$ c. 

6,425 . 25 
3,463.55 
1,826.60 


$ c. 

2,792.36 
1,201.42 


$ c. 

2,016.86 
1,677.89 


$ c. 

37,863.94 
22,212.24 
23,502.85 








2,766.94 


1,508.00 


1,830.00 


1,836.00 


592.00 


1,496.50 


8,172.90 


363 . 29 


1,013.48 


5,093.99 


709.52 


104.92 




2,838.90 


12,929.53 


18,851.89 


310,074.43 


14,260.92 


4,690.70 


5,191.25 


97,357.77 


7,263.50 


10,635.37 


133,259 80 
5,155.05 
3,222.67 

18,450.85 

852.15 

5,377.77 

2,044.74 

9,335.17 
216.79 

7,519.97 
13,008.98 
12,678.45 

3,319.30 

7,912.95 

11,142.78 
19,218.00 
25,744.76 


10,133.61 


3,392.60 


3,377.46 


68,252.96 














751.52 


1,594.48 

44.46 

296.74 


886.32 


317.43 


105.50 


2,860.38 
493 . 18 




42.63 


96.57 




480.86 






521.69 


121.00 


138.46 

37.24 

969.33 

510.82 


113.26 


57.09 


27.34 


1,184.90 




595.74 
611.09 
200.85 






2,610.25 


358.46 


304 . 23 


301.90 


6,405.06 
1,446.13 


183.66 


362.41 
1,153.09 

636.30 

897.00 






217.20 


1,098.33 

1,775.58 

843 . 00 


1,766.00 

825.76 

1,108.00 


234.54 
464.45 
254.00 


437.17 
711.11 
277.00 


5,470.74 
4,778.81 
3,427.00 














12,395.05 


17,275.70 


278,460.18 


16,283.26 


5,120.91 


5,237.48 


98,149.16 


534.48 


1,576.19 


31,614.25 












2,022.34 


430.21 


46.23 


791.39 










281 

64 

3 


318 
S3 

7 


5,620 

878 
143 


309 
69 

6 


150 
36 


78 
36 


1,830 

334 

76 










348 


408 


6,641 


384 


186 


114 


2,240 



380 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



EASTERN ONTARIO 
SYSTEM— Continued 



Municipality 


Madoc 
1,059 


Marmora 
924 


Martintown 
P.V. 


Maxville 


Population 


785 






Earnings 
Domestic service 


$ c. 

4,856.28 
3,484.56 
1,016.60 


$ c. 

3,613.94 

1,496.46 

131.40 


$ c. 

807.82 
987.08 


$ c. 
3,191.96 


Commercial light service 


2,396 57 


Commercial power service 




Municipal power 






Street lighting 


1,524.00 


1,448.00 


300.00 


1,430.04 


Merchandise 




Miscellaneous 


69.12 


97.87 


93.42 


30.65 






Total earnings 


10,950.56 


6,787.67 


2,188.32 


7,049 22 






Expenses 
Power purchased . 


6,878.33 


4,194.82 


1,085.89 


4,888.65 


Substation operation 


Substation maintenance 










Distribution system, operation and 
maintenance. 


566.96 


53.65 


29.55 


214.57 


Line transformer maintenance 




Meter maintenance 


45.44 








Consumers' premises expenses 








Street lighting, operation and main- 
tenance 


193.85 


76.50 


38.70 


59.42 


Promotion of business 




Billing and collecting 










General office, salaries and expenses. . 
Undistributed expenses 


1,091.32 


503.51 


130.50 


304.13 


Truck operation and maintenance. . . 










Interest 


70.54 
447.48 
374.00 


551.35 
720.86 
539.00 


195 . 19 
328.21 
135.00 


474.86 


Sinking fund and principal payments 
on debentures. . 


872.41 


Depreciation 


481.00 


Other reserves 














Total operating costs and fixed 
charges 


9,667.92 


6,639.69 


1,943.04 


7,295.04 






Net surplus 


1,282.64 


147.98 


245 . 28 




Net loss 


245.82 












Number of Consumers 
Domestic service 


260 

98 

6 


198 

44 
2 


35 
22 


132 


Commercial light service 


43 


Power service . . 










Total 


364 


244 


57 


175 







934 



HYDRO-ELECTRIC POWER COMMISSION 



381 



"B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Napanee 
3,014 


Norwood 

727 


Omemee 
498 


Oshawa 
23,002 


Ottawa 
130,672 


Perth 
3,994 


Peterborough 
22,809 


$ c. 

26,679.48 

13,744.34 

12,225.60 

1,467.01 


$ c. 

4,480.44 

2,176.66 

626.22 


$ c. 

2,249.60 
1,268.12 
1,452.73 


$ c. 

148,818.93 
57,042.47 

134,048.33 

6,366.23 

10,573.28 


$ c. 

421,647.54 

159,028.96 

54,871.97 

29,594.68 

72,933.23 


$ c. 

22,755 . 27 
15,109.94 
16,128.17 
2,075.60 
2,066.00 
1,452.85 
1,949.87 


$ c. 

117,648.00 

57,718.24 

73,455.92 

6,386.77 


4,473.94 


1,578.00 


924.00 


19,518.00 


767.94 


400 . 5 1 




5,619.03 




1,280.86 










59,358.31 


9,261.83 


5,894.45 


362,468.27 


738,076.38 


61,537.70 


276,007.79 


37,613.44 


3,971.85 


2,779.53 


328,295.17 


368,718.84 

23,876.25 

609.01 

23,828.68 
2,020.19 

10,443.72 
3,471.66 

25,698.32 
10,463 . 05 
36,755.94 
20,630.80 
22,146.16 
2,308.87 
47,700.61 

21,224.29 

71,594.00 

19,000.00 


38,116.49 
360.00 


196,442.92 
5,998.99 










356.46 


4,264.78 
418.45 


728.76 


375.10 

2.50 

79.84 


5,912.29 
367.06 

947 . 14 

145 . 15 

1,677.49 
618.48 
9,182.16 
4,691.14 
3,821.12 


1,348.51 

48.86 

597.82 


5,543.76 
850.54 


1,114.00 




4,696.52 


55.52 




267.11 


989 . 79 


120.00 


40.39 


522.75 


3,067.29 


1,599.02 






1,440.35 

3,100.09 

735.21 

401.22 

2,880.45 

1,819.09 
3,224.00 


6,369.51 


3,880.12 
2,046.57 


479.36 


264.06 


6,349.90 
5,102.62 


94.18 


189.55 
1,743.04 

1,026.21 

1,027.00 




2,423 . 03 


1,682.49 
2,384.96 
1,529.00 


235.97 
760.29 
558.00 


12,755.46 

11,063.49 

9,162.00 

964.86 


27,488.77 

14,263.54 

15,627.00 

1,200.00 












57,672.32 


9,285.77 


5,095.68 


389,603.01 


710,490.39 


54,594.84 


296,047.96 


1,685.99 




798.77 




27,585.99 


6,942.86 






23.94 


27,134.74 


20,040.17 












770 
190 

35 


217 
70 

2 


126 

47 

6 


5,878 

510 

98 


12,491 

1,382 

214 


934 
192 

25 


5,274 
774 

155 


995 


289 


179 


6,486 


14,087 


1,151 


6,203 



382 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



EASTERN ONTARIO 
SYSTEM— Continued 



Municipality 


Picton 

3,217 


Port Hope 
4,626 


Prescott 
2,952 


Richmond 
381 




Population 


P V 






Earnings 
Domestic service 


$ c. 

21,579.51 

12,218.11 

6,746.07 

1,883.78 

4,364.04 


$ c. 

29,372.14 

11,563.02 

22,168.35 

2,101.20 

4,615.00 


$ c. 

15,796.30 
8,332.02 
3,234.08 
1,522.81 
3,475.00 


$ c. 

1,868.77 
1,551.59 


$ c. 

2,535.67 
1,284.49 


Commercial light service 


Commercial power service 


Municipal power 






Street lighting 


500.00 


736 00 


Merchandise 




Miscellaneous 


1,588.57 


144.58 


149.55 


5.31 


30 08 






Total earnings 


48,380.08 


69,964 . 29 


32,509.76 


3,925.67 


4,586.24 




Expenses 
Power purchased .... 


37,408.54 


45,161.39 


24,633.82 

1,213.64 

11.71 

2,019.29 

88.00 

181.45 


2,839.73 


2,863.50 


Substation operation 


Substation maintenance 










Distribution system, operation and 
maintenance 


2,076.15 

94.37 

464 . 19 


2,285.05 

13.77 

1,210.08 

1.50 

778.79 


44.13 


54.51 


Line transformer maintenance 




Meter maintenance 






Consumers' premises expenses 






Street lighting, operation and main- 
tenance 

Promotion of business 


411.83 

7.12 

1,167.77 

3,255.55 

185.32 

247.94 

54.29 


714.66 


14.36 


112.28 


Billing and collecting 


1,973.95 

4,400.15 

958.68 

209.76 

1,422.16 

2,819.40 

1,828.00 


1,106.59 

2,066.11 

397.40 






General office, salaries and expenses. . 
Undistributed expenses 


216.10 


285.82 


Truck operation and maintenance . . . 
Interest. . . 








343.65 
223.05 
190.00 


419.60 


Sinking fund and principal payments 
on debentures 


2,633.00 


417.19 


Depreciation 

Other reserves 


1,832.00 


271.00 














Total operating costs and fixed, 
charges 


47,205.07 


63,062.68 


35,065.67 


3,871.02 


4,423.90 






Net surplus . 


1,175 01 


6,901 61 




54 65 


162 34 


Net loss . 


2,555 91 














Number of Consumers 
Domestic service 


997 

204 
38 


1,238 

203 

45 


655 

155 

19 


53 
24 


107 


Commercial light service 


33 


Power service 










Total 


1,239 


1,486 


829 


77 


140 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



383 



4t B"— Continued 

Hydro Municipalities for Year Ended December 31, 1933 



Smiths Falls 
7,501 


Stirling 
865 


Trenton 
6,331 


Tweed 
1,247 


Warkworth 
P.V. 


Wellington 
. 900 


Westport 
733 


$ c. 

41,684.74 
15,246.98 
16,534 14 


$ c. 

5,346.26 
3,351.71 
1,812.83 
234.45 
1,433.00 


$ c. 

28,302.03 

17,524.57 

66,346.34 

1,897.90 

8,076.00 


$ c. 

6,324.50 
4,460.90 
2,096.34 
204.57 
1,886.25 


$ c. 

2,185.13 
1,551.15 


$ c. 

4,733.77 
2,067 . 20 
2,128.95 


$ c. 

3,198.24 
2,906.93 


225 00 






8,342.30 


643.75 


1,160.04 


1,705.00 


3,260.40 


408.27 


2,102.88 


10.88 


140.80 


261.27 


122.27 


85,293.56 


12,586.52 


124,249.72 


14,983.44 


4,520.83 


10,351.23 


7,932.44 


45,792.24 

1,921.00 

373 29 


7,625.67 
108.95 


85,336.89 


9,164.96 


3,244.39 


7,728.80 


4,791.34 


15.87 

2,346.73 

57.07 

1,752.11 

364.32 

1,502.64 
16.10 
2,632.19 
4,651.08 
1,455.72 
733.61 
7,562.22 

5,366.67 

3,539.00 










2,991.14 
16.66 


1,047.86 


867.73 


48.35 


630.31 


251.99 

47.26 


1,006 02 


72.69 

75 

375.34 
69.76 
429.46 
1,022.46 
217.01 
367.75 


166.22 

35 

403.30 

48.62 

562.04 

1,000.75 

232.50 




25.67 


93 








742.72 


20.00 


150.52 


110.48 


3,371.85 








4,167.55 
1,016.51 


175.67 


625.87 

42.57 


418.33 
25.50 


609 . 48 






4,835.95 


683.21 
647.34 
440 . 00 


581.61 
221.76 
199 . 00 


828.77 
640.02 
694 . 00 


804 . 55 


12,329.72 
5,712.00 




453.85 


953 . 00 


207.00 
















84,886.13 


12,290.70 


117,332.22 


14,217.02 


4,490.78 


11,366.53 


7,111.23 


407.43 


295.82 


6,917.50 


766.42 


30.05 




821.21 




1,015.30 
















1,640 

257 
44 


268 
80 
10 


1,251 

220 

48 


249 
92 
12 


106 

43 


284 

64 

6 


96 

49 








1,941 


358 


1,519 


353 


149 


354 


145 



384 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT 
Detailed Operating Reports of Electrical Departments of 



EASTERN ONTARIO 
SYSTEM— Concluded 



Municipality 


Whitby 
5,294 


Williamsburg 
P.V. 


Winchester 
963 


EASTERN 
ONTARIO 




SYSTEM 
SUMMARY 






Earnings 
Domestic service 


$ c. 

19,548.69 

9,555.38 

14,189.33 

2,312.74 

3,716.43 


$ c. 

3,702.03 

7,503.38 

231.98 


$ c. 

5.870.21 
3,363.90 
1,548.03 


$ c. 

1,377,574.45 

661,352.71 

715,964.74 

93,135.34 

248,809.48 

2,432.01 

43,581.42 


Commercial light service 


Commercial power service 


Municipal power 


Street lighting 


192.00 


1,062.00 

36.87 

363.54 


Merchandise. 


Miscellaneous 


1,355.95 


165.44 




Total earnings 


50,678.52 


11,794.83 


12,244.55 


3 142 850 15 






Expenses 
Power purchased 


37,949.47 


5,726.19 


8,812.03 


1,984,639.39 
44,048 88 




Substation maintenance 


162.12 

2,861.02 

45.31 

456.78 

75.77 

699 . 47 

144.80 

1,588.13 

1,581.45 

251.89 

203 . 85 

2,175.59 

3,475.42 

2,837.10 






5,421.01 


Distribution system, operation and 
maintenance 


721.37 


577.53 


106,793.88 


Line transformer maintenance 


7,512.57 


Meter maintenance 






36,551.43 


Consumers' premises expenses 






7,542.11 


Street lighting, operation and main- 
tenance 


60.75 


178.95 


56,176.49 


Promotion of business 


13,085.60 


Billing and collecting 






94,627.71 


General office, salaries and expenses. . 
Undistributed expenses 


378.24 


902.46 


116,169 12 

60,506.02 


Truck operation and maintenance . . . 
Interest 






14,039.53 


82.00 
200.15 
181.00 


389.22 
384 . 48 
598.00 


158,412.73 


Sinking fund and principal payments 
on debentures 


130,523.35 


Depreciation 


176,758.10 


Other reserves 


47,409.62 












Total operating costs and fixed 
charges 


54,508.17 


7,349.70 


11,842.67 


3,060,217.54 






Net surplus. . . 




4,445 . 13 


401.88 


82,632.61 


Net loss. . . 


3,829.65 












Number of Consumers 
Domestic service 


833 

158 

21 


92 

63 

1 


277 

68 

2 


54,152 


Commercial light service 


8,707 


Power service 


1,327 


Total 


1,012 


156 


347 


64,186 







1934 



HYDRO-ELECTRIC POWER COMMISSION 



385 



"B"— Concluded 

Hydro Municipalities for Year Ended December 31, 1933 



THUNDER BAY 
SYSTEM 


Fort William 
25,188 


Nipigon 


Port Arthur 
19,749 


THUNDER 

BAY 

SYSTEM 

SUMMARY 


ALL 
SYSTEMS 

GRAND 
SUMMARY 


$ c. 

200,550.28 
61,130.12 
43,150.68 
23,404.22 
17,029.60 


$ c. 

2,510.41 

1,831.65 

255.31 

724.63 

510.00 


$ c. 

107,395.49 
51,764.78 

732,490.93 
37,667.09 
18,984.96 


$ c. 

310,456.18 

114,726.55 

775,896.92 

61,795.94 

36,524.56 


$ c. 

11,429,101.13 
6,013,025.96 
9,080,522.07 
1,826,872.07 
1,779,582.48 
12,812.74 


7,331.24 




18,566.30 


25,897.54 


485,925.43 








352,596.14 


5,832.00 


966,869.55 


1,325,297.69 


30,627,841.88 


269,607.02 
6,169.16 


3,115.86 


855,196.51 

19,665.66 

1,066.32 

12,045.49 
1,570.58 
3,866.33 


1,127,919.39 

25,834.82 

1,445.14 

22,609.93 

1,883.83 

10,572.55 

293.48 

13,214.39 
1,822.05 

20,913.23 

16,657.35 
9,181.79 
2,846.96 

41,106.18 

21,454.89 
42,481.14 
19,857.32 


19,330,861.58 
484,764.57 


378.82 




288,583.29 


10,090.24 

283.77 

6,665.82 

293.48 


474 . 20 
29.48 
40.40 


895,350.99 

82,321.32 

283,115.98 

361,499.20 


6,307.37 


19.88 


6,887.14 
1,822.05 
9,826.46 

10,474.79 
4,873.80 
1,245.52 

17,768.51 

8,780.03 
30,021.77 
18,213.50 


353,082.15 
259,936 42 


11,086.77 




817,660.03 


5,589.70 
4,307.99 


592.86 


908,517.79 
349,101.36 


1,601.44 




105,452.68 


22,960.97 

12,241.58 

11,986.37 

1,643.82 


376.70 
433 . 28 
473.00 


2,426,286.35 

2,319,319.09 

1,894,714.87 

94,285.54 








371,214.32 


5,555.66 


1,003,324.46 


1,380,094.44 


31,254,853.21 




276.34 








18,618.18 


36,454.91 


54,796.75 


627,011.33 








5,260 

827 
98 


134 

39 

2 


4,053 

728 

97 


9,447 

1,594 

197 


452,557 
73,628 
12,813 


6,185 


175 


4,878 


11,238 


538,998 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



387 



STATEMENT "C" 

Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing 
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita. 



Municipality 



Population 



Number 

of 

lamps 



Size and 
style of 
lamps 



Rate per 

lamp 

per annum 



Total cost to 

municipality 

per annum 



Cost 

per 

capita 



Acton 



Agincourt 

Ailsa Craig. . . 

Alexandria. . . . 

Alliston 

Alvinston .... 



Amherstburg. . 

Ancaster Twp. 

Apple Hill.... 

Arkona 

Arthur 



Athens. 

Aylmer. 

Ayr.... 
Baden . 



Barrie 



Bath 

Beachville 



1,895 



464 
2,340 
1,379 

690 

3,086 



416 
1,037 

582 

1,989 

768 



7,455 



350 



127 

5 

61 

1 

3 

58 

61 

1 

95 
41 

102 
13 

84 

6 

81 

9 

23 

12 

32 
49 

33' 

48 

92 

40 
23 

168 
24 

1 

92 
3 

65 

464 
15 
41 
23 

21 

47 



80 c.p. 

80 c.p. 
100 watt 
150 watt 
300 watt 

100 watt 

100 watt 
200 watt 

100 watt 
200 watt 

100 c.p. 
100 watt 

100 watt 
200 watt 

100 c.p. 
250 c.p. 
200 watt 
300 watt 

100 watt 
150 watt 

100 watt 

100 watt 

100 watt 

100 watt 
200 watt 

100 watt 
300 watt 
Traffic Light 

100 watt 
500 watt 

100 watt 

100 c.p. 
100 watt 
200 watt 
300 watt 

100 watt 

1,00 watt 



$ c 
9.00) 

12.00 
9.00 

12.00 

20. 00, 

13.00 

10.00 
18.00 

17.00) 
25.00/ 

18.00) 
18.00/ 

20.00\ 
29.00/ 

15.00] 
30.00 
20 . 00 ( 
30.00J 

12.50) 
15.00/ 

17.00 

20.00 

19.00 

14.00) 
30.00/ 

10.00) 
25.00[ 
40.00J 

10.00/ 
36.00/ 

10.00 

9.00) 

17.00 
22.00 
25. 00 J 

34.00 

11.00 



$ c. 
1,824.00 

750.04 
620.50 

2,640.00 

2,070.00 

1,854.00 

2,270.22 

1,135.00 

559.75 

960.00 

1,748.00 

1,250.00 

2,320.00 

1,028.00 
650.00 

5,961.25 

714.00 
517.00 



**Population not shown in Government statistics. 5 Series system. m Multiple system. 
tfPart cost paid direct in the form of debenture charges. 



388 



TWENTY-SIXTH ANNUAL REPORT OF THE 



No. 26 



STATEMENT "C"— Continued 

Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing 
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita. 



Municipality 


Population 


N 


umber 

of 
amps 


Size and 
style of 
lamps 




Rate per 

lamp 

per annum 




Total cost to 

municipality 

per annum 


Cost 

per 

capita 


Beaverton 


960 


1 


9 
104 


100 watt 
100 watt 
500 watt 


m 
m 
m 


$ c. 
7.001 
10.00 
30.00J 


$ c. 
1,286.52 


$ c. 
1.34 


Beeton 


584 


{ 


65 
14 


150 c.p. 
100 watt 


s 
m 


15.00\ 

15.00/ 


1,185.00 


2.03 


Belle River 


746 




63 


100 watt 


m 


11.00 


693.00 


.93 


Belleville 


14,059 


1 
1 


542 
22 
52 

103 


100 c.p. 
400 c.p. 
1,000 c.p. 
300 watt 


s 
s 
s 
m 


9.001 

28.001 
52.00 
33. OOj 


11,655.86 


.83 


Blenheim 


1,690 


J 
1 


163 
12 


150 c.p. 
400 c.p. 
600 c.p. 
Traffic Light 


s 
s 

5 

HI 


12.001 
28.00 
37.00 
16. OOJ 


2,500.00 


tt 


Bloomfield 


614 




60 


80 c.p. 


s 


12.00 


720.00 


1.17 


Blvth 


602 




100 


100 watt 


111 


13.00 


1,300.00 


2.16 


Bolton 


593 


f 45 

I 23 


100 watt 
200 watt 


m 
m 


13.00\ 
23.00/ 


1,113.99 


1.88 


Bothwell 


646 


J 
1 


66 
21 


100 watt 
300 watt 


m 

m 


11.00\ 
27.00/ 


1,293.00 


2.00 


Bowman ville. . . 


3,641 




171 

4 

42 


80 c.p. 
150 watt 
300 watt 


s 
m 
m 


14.001 
27.00 
37.00J 


4,057.17 


1.11 


Bradford 


1,009 


\ 


' 60 


80 c.p. 
100 watt 


s 
m 


19.001 
19.00/ 


1,273.00 


1.26 


Brampton 


5,413 




f 659 


100 watt 
500 watt 
Fire Alarm 


m 
m 


8.001 

35.00l 

6.50j 


5,426.50 


1.00 


Brantford 


30,724 


* 


[ 149 

3,501 

10 

12 

2 

2 

20 


1,500 c.p. 
100 watt 
150 watt 
200 watt 
300 watt 
500 watt 
750 watt 


s 
m 
m 
m 
m 
m 
m 


45.00 
7.50 
8.50 
11.00 
16.00 
45.00 
46.00 


• 


34,414.16 


tt 


Brantford Twp. 






369 
32 


100 watt 
100 watt 


m 
m 


11.00 
18.00 


4,250.50 
576.00 


** 


Brechin 


X 


** 


Bridgeport 






58 


100 watt 


m 


10.00 


580.00 


** 













**Population not shown in Government statistics. s Series system. 
ttPart cost paid direct in the form of debenture charges. 



m Multiple system. 



^Includes Mara and Thorah Townships. 



1934 



HYDRO-ELECTRIC POWER COMMISSION 



389 



STATEMENT "C"— Continued 

Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing 
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita. 



Municipality 


Population 


Number 

of 

lamps 


Size and 

style of 

lamps 




Rate per 

lamp 
per annum 


Total cost to 

municipality 

per annum 


Cost 

per 

capita 


Brigden 




r 4i 

I 21 


60 watt 
100 watt 


m 

m 


$ c. 

11.001 

14.00/ 


$ c. 
745.00 


$ c. 
** 








Brighton 


1,413 


137 


80 c.p. 


s 


12.00 


1,644.00 


1.16 


Brockville 


9,615 


■ 


' 589 

15 

35 

49 

6 


100 c.p. 
1-Lt. stds. 
3-Lt. stds. 
5-Lt. stds. 
300 watt 


s 

m 
m 
m 

m 


11.00 
17.00 
21.00 
24.00 
24.00 


' 


8,772.50 


.91 


Brussells 


770 


/ 80 
I 18 


100 watt 
200 watt 


m 

m 


12.001 
18.00/ 


1,284.00 


1.67 


Burford 




67 
24 


100 watt 
100 watt 


m 
m 


11.00 
13.0 


737.04 
312.00 


** 


Burgessville. . . . 




** 


Caledonia 


1,400 


f 158 

20 

I 8 


100 watt 
100 watt 
100 watt 


m 
m 
m 


8.001 

9.50} 

13.00J 


1,546.98 


1.10 


Campbellville. . 




19 


100 watt 


m 


24.00 


456.00 


** 


Cannington. . . . 


851 


11 


100 watt 
300 watt 
500 watt 


m 
m 
m 


14.00] 

22.00 
32.00J 


1,022.00 


1.20 


Cardinal 


1,305 


/ 16 
I 41 


100 watt 
- 200 watt 


m 
m 


15.001 
21.00/ 


1,066.00 


.81 


Carleton Place . 


4,272 


{ 84 
\ 102 
1 67 


60 watt 
200 watt 
300 watt 


m 
m 
m 


12.00] 

18.00} 
23.00J 


4,385.00 


1.03 


Cayuga 


705 


85 


100 watt 


m 


18.00 


1,431.00 


2.03 


Chatham 


16,223 


f 35 

7